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E O ❑ O ❑ ❑ ❑ m c m m m m m CJ Ci M Ci Ci Ci � N a N — ¢ E E E - p y n Z � U U U U U U U N p U 2 rn m 0 o o❑ w IL `w 3 3 2 E O 0 r O a rn N N r N � N � U m U E o o ¢ U U a O O b N O Z a+ o U o n � o z a (� z� 3 H u e N � io m m Li Y N � N i O d Q � a � U LU N IL L a 0 W V u 0 C U J O Q o Ja A N � ON n E �1N V � r o U r J Q W N m C C z Z � > O N m N � Q N N Q a ❑ Y Q Q c Z E 0 � E m z d � o co N c ❑j � m a m 3 N d O p � N a u c E a`r a ❑ � E o v U a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li Performed: Suspend E-1 Perforate ❑ Other Stimulate El After Casing 1-1 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to WINJ ❑Q 2. Operator 14.ell Class Before Work: 5. Permit to Drill Number: Name: COnOCOPhIIIIpS AlaSka, Inc. velo ment Exploratory p ❑ p ry ❑ Stratigraphic ❑ Service ❑ 1 219-055-0 3. Address: P. O, BOX 100360 6. API Number: Anchorage, Alaska 99510 1 50-029-22419-61-00 7. Property Designation (Lease Number): 8, Well Name and Number: KRU 2E-171-2 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 feat true vertical 6,366 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 Burst 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 12,947 6,109 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 SSV NO —S and SSSV (type, measured and true vertical depth) BAKER 7' x 3-117' 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-Mct I Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - - - Subsequenttooperation: - 1126 1534 12639 14. Attachments fmquimd per 20 nnc 25.70, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑ Service 0 Slretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status afterwork: Of ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 21 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319 354 Contact Name: Alex Trower Authorized Name: Lynn Aleshire Contact Email: alexi.tr"er@conocophillips com Authorized Title: Staff Petroleum Engineer cl Contact Phone: (907) 263-3733 Authorized Signature: Date: vr1 10/15/i 9 /�V7 Form 30-004 Revised4/2017 RBDMS"OCT 1 12019 Submit Original Only 2E-171-2 DAILY REPORT OF WELL OPERATIONS 812812019: 2E-17 was brought on water injection after completion of workover, CTD sidetrack and permanent connection to waterflood facility ConocoPhillips Alaska. Inc. KUP INJ WELLNAME 2E-17 WELLBORE 2E -17L2 MAIL' 3 2E -11u, 1O 10ZV s0FM Last Tag V,Nid xMma4 (xlull AnnaGlion O,PM ME) End O.re Welllwle L,si Moa By lA TTO 2E -PLY jennall Last Rev Reason Annotation End D,R W I(Ene UstM By REV REASON'. CTD Lateral ,', jennall Casing Strings nxmB DeeeNyBon ODIIn) IOn, roP mN8) sem,Pm mHe) Set D,d,,WDI...w1/Len9... Gme¢ T.TLTIH a L2 LATERAL (CTD) 23/8 1.99 9,28fi0 12947E 760 L-80 STL Notes: General & Safety End mh AnnMaron 71110111 NOTE. View SCNemalicw)Alaska Scnemaliciuv NANGER:26.0 CONOUCTO;11,11210 GASLIFT:20 e SUR.S; 4I S-,A&79— G UFr; 4,M2 GASLIFT:E. s GAS LIFT. 151.5 GA.SUFT,&YH.S G45 UFT; &W 6 LOGTOR:&71&6 SF.KER.&7N&7I18 PACKER: .9 IANDINGNIPPLE.S.7060 OUTERWEOGE;&BJ,.O WKIPSTOCKSW70 IANPLE:&Bt&I X4vk Fkw R-T.TNUSW. B,Bi&I OUTER WEDGE; &@&B WXIPLTC K,BPO GMTO CCOLiRACK&lA B.R70 %{xF FbxThu bA: S&T7.0 WIOING NIPPLE: B,Yt].B CARING SCWER:S 4.0 FLOPT SHOE B.BSI.O s PROOUCTION:,1 &9=0� L2 IATERM (UD): B,2N6 12.NT4 THE STATE OfALASKA 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 -17L2 Permit to Drill Number: 219-055 Sundry Number: 319-354 Dear Mr. Trower: AIaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vvv✓sv. a0gcc.alaska.gov Enclosed is the approved application for the su Please note the conditions of approval ndry approval relating to the above referenced well. 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. Commissioners_ S DATED this !-sdaayG,o of August, 2019. 3BDMSZ AUG 161019 STATE OF ALASKA .0 31 2'31',J ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 REVISION 1. Type of FQbeY 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 WINJE1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development o • Stratigraphic ❑ Service ❑ 219-055-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22419-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2E-171-2 Will planned perforations require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 256581 ADL25665 /4 �H- Kuparuk River Field / Kuparuk River Oil Pool - 11. T t,; /? PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,936' 6,109' 12936 6109 3000psi Casing Length Size MD TVD Burst Collapse Conductor 80' 16'• 121' 121' Surface 4,439' 95/8 4,481' 3,473' Production 9,164' 7" 9,206' 6,380' Liner 3,661' 23/8 12,947' 6,109' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NIA NIA 3.500" L-80 8,862' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER FHL PACKER MD= 8735 TVD= 6014 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 O 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 %/11 Contact Phone: (907) 263-3733 Authorized Signature: Date: r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 1 Gi _ TJ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test MI/ Location Clearance ❑ Other: RBDMSI�UG 16 2019 Post Initial Injection MIT Req'd? Yes ❑ ,I LL Spacing Exception Required? Yes ❑ No Subsequent Form Required: f — �7 U-/ APPROVED BYg Approved b . COMMISSIONER THE COMMISSION Date: rT`81`¢l19 0-((n ORIGINAL Fo -403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. bmit Form and Attachments 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 it 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. -T 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 Y, 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. {E /\ . . § 74 ADL025658 T1 I NR9L T10NR9E N 0 0.1 0.2 0.3 o Miles I ConocoPhillips Alaska 2E-17 Injection Analysis 7/24/2019 17 2E-1711 Well Paths Well Trajectory 2E-17 Open Interval 2E-171-1 Open Interval 2E-171-2 Open Interval �E-17L1PB1 Open Interval 2E-17L1PB2 Open Interval �2E-171-2PB1 Open Interval L1 G ^�^. ro �_ x z AD r- e T11NIRIOL 1101AIR10E '�, 0-) CD \ADL025664 Well Open Interval 114 Mi Buffers 2E-17 01114 Mi Buffer O 2E -17L1 011/4 Mi Buffer Q2E-17L1PB1 01114 Mi Buffer 2E-171-1 PB2 011/4 Mi Buffer 2E-171-2 01114 Mi Buffer O 2E-17L2PB1 011/4 Mi Buffer Other Wells — Active P&A'd Gravel Footprint = CPAI Lease KUP PROD WELLNAME 2E-17 7LLBORE 2E-17 Lonocopnoups^„^W�w.. ^.x^„e`-,a' ,� nel4 Name WeII1kar ap Wa WeIIMreSrarus ncl '1 MGINKB -slat INK91 Alaska, Inc. KUPARUK RIVER UNIT 500292241900 PROD 8.00 6,16].39 9.206.0 Comment XxS 1ppm OaN MnoWm EnE Oale KBGM IN) fllg Release Dalc SSSV; NONE LAST WO: 3242019 41.50 11112711993 111I.Aamte&la-x9AM Last Tag cal.enerxmss Tuan Mtw,irkn BegnmKel End pale Vii lest MW an, LAST TAG: ZE9 ilemprom IFNlR zsn- Last Rev Reason Annotation End Dala WenWre l,'t MoO By Rev Reason: Seth$ Inner Wedge 4512019 ZE-ll lama] Casing Strings Lasing Gezcripllon 00(in) ID (in) TOp INKIB $N Beath MKB1 set Goal, D VHL.. Waren l l... Gratle Tomall ri COrvDUCTOR 16 15.06 41.5 121.p 121.0 62.58 H-40 WELDED Oasma Orvcripai On Ilan 10 (In1 TopryMB) Set Dep HOB/ Sat OepN(TVOI...Waren p.., Gratle Top Thread SURFACE 9518 0.92 41.5 4,480.8 3,4]3.3 38.00 d55 OTC Casae OeolpNon 00(In) ID(IN Top Bake) set Oepm IOKBI Set Ooup Tend. Waen(I... Orad& Top T,rcad mxcucioq-aysrzl_o PRODUCTION ] 8.28 30.6 9,198.0 6,380.4 28.00 LA0 BTC -MOD NnJn Nb-poH SO ;tato YxYmte Caaly O¢ulpllon 00(IN ID (in) Top1B.11 L2 Lateral (CTD) 23/8 1.99 9,286.0 Set Oand 1I $M@pM ITVD)... WM.N 0...1. Top, 12,94].4 4.60 LA0 STL Tubing Strings TUBIOeacnpunn sump Ma.../DON TUBING- 3112 299 TP 21. lttxel 264 satOS IR.. axi Set O.9lh (iVG (... Ige 6.114.9 9,30m 9.30 Gaade LA0 EULnnn¢tmn EUE BRM ORS UFT: x.aTJ.e PRODUCTION oat On Details Top HoOl Top no Nornme Tup(aKB) (Real 1 Wm Dm Com IS pnl MG 26.0 0.00 HANGER Cameron CXS Tubing Hangar(] 1116' x 312- EUE BRM BxP) 2.992 .UK.. a1.SUaps- 0,718.6 6,001.1 37.41 LOCATOR Locator Sub. Baker (-X of.a.om) 2.992 0,721.6 ,003.5 37.40 SEALASSY Seal Assembly, Baker, 0640 2.992 GAS LIFT: {Mas 8,]34.9 6,014.0 37.40 PACKER Baker? 0: 112-FHLPader 2.992 A alxx Poll - Seeunuc 8.788.0 6,056.2 37.34 Landing Nipple HES3.12"x2013^XN,,Ae Prafile- 2.813 gtaoe,ay.a'xrzvnls 8,804.0 6,069.0 37.37 OuNrWedge Nonhem Soutions 350-700 Outer Wedge 2.990 cAs uPT; e.aze 8,818.1 8.080.2 37.39 LANDING HES 11)2' x 2.013" X Nipple Prafile- Bakerloch 2.813 NIPPLE 8,823.9 6.084.8 37.39 Outer Wedge NOMem SNudans3567000uter Wddge 2.990 8.83].9 6.095.9 37.30 LANDING HES 3.12' x 2.813- X Nipple Profile - Bakerbak 2.813 GAS LIFT: 7,51&5 1NIPPLE 8,849.1 6,104.8 37.35 CASING Trailblazer on, scraper 2.510 SCRAPER 1 8,ram U I 6,113.4 37.33 FLOAT SHOE Flom shoe 2.992 GAS UFT: &xxa.3 Other In Hole (Wlrellne retrievable plul Is, valves, pumps, Hsh, eto.) Top(TVD) Top Incl Tap(hKB1 HKB) (y Des Com Run 011e ID (Ind 8,197-0 40634 37.36 Fish CID Culmak CTD dolling BHA. Stuck in window win 2- CT on 512312019 GASOFT:9,6626 Coilaack BHA top 8,807.0 6.071.4 37.38 WHIPSTOCK Norman Solution F1350 inner Wedge WI 3 HATI S' 5152019 from top. OAL 12' max W 2.625' 81818.1 6,080.2 37.392.81 -X -Lack 2.81`X-IOWlbw wl now into sub 5/52019 1]50 I.0CATOR;&71&6 Flow Thru Sub sane Aesv:ente 8,85-0 6987.2 37.40 WHIPSTOCK Northern SOWtion F1350 Inner Wedge Wl 3 RA Tags S' 652019 PACKER: mom from top. DAL 12 max ad 2.625" 0,837.0 6,095.2 37.38 TfIr X1.k 2.01- Matt, Dow wl Bos in,. sub 4/42019 1.750 Fl.Thru Sub Marginal Inserts LUdira Nard.,a]9&0 Sl as N Top Top) Tapmmel done) Make III I- Ietall Po,tS2e TRO Run 00uld Sen, Type TyPe (IN (Pal) Run Dek Lour 2,873.8 2.496.4 Comma MMG 112 GAS LIFT GLV RK 0.188 1,263.0 41412019 2 4,883.2 3.706.7 Camco MNG 1112 GAS LIFT GLV RK 0.188 1,259.0 41412019 OHIPST. e:a.. WXIPsiO0(: 9.to'l.0 3 6,402.8 4,541.4 Cam. MMG 112 GAS LIFT GLV RK 0.188 1,256.0 4112019 d 7,518.5 5,202.0 Cam. MMG 112 GAS LIFT GLV RK 0.188 1,254.0 4I12019 5 8.229.3 5.850.0 Co.. MMG 112 GAS LIFT GLV RK 0.188 1,2500 41312019 t/uNgIKi NI PRE: a 1111 LAN IFIGNFbx Tlvu&8; ars, 6 8,662.7 5,954] Co.. MMG 1112 GAS LIFT OV RK 0.250 0.0 41312019 Notes: General & Safety eAmt Eta no. Anndaann .-WeaessGodra 41212019 NOTE: Vote SLhematiC w/ Alaska SChema0C10.0 W W P..K; a.. CTO Cank & FM x 11 8]W.0 2u'.R-TM1vsLL; &&i].0 tMTMNGNIPPLE:o.aaT.a CASING SGiMER;B&AO FLOAT SHOE. 6aW n PRODUCTION', MAGIGG0 a taNnl for.): A%.O 1zee.a §j� gm .( § » Olt $ # 4 7} \k}kkk\k\\\k§ Loepp, Victoria T (CED) From: Trower, Alex 1 <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 -17L1, 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. Tha nx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(41alaska.go 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@conocophil lips.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-171-2 (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 -17L3 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 3M-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 Y4 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 1/4 -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 mgA 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 AAr. 25 win Z/I &IVED SUR 0 ao1i 117 AOG4�C 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Reper Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing El OtherO to IN ❑� 2. Operator Name: 4. Cunent Well Cis": 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Ezplonnory ❑ Development Stratigraphic El Service 187-026 ' 3 Address: API Number. o 50-029-21707-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-06 r Will planned perforations require a spacing exception? Yes 0 No ❑✓ 9, Property Designation (Lease Number): 10. Field/Pool(s): ADL 25521 Kupamk River Field/ Ku aruk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (N): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): g.1gq '?L,&D• 1o7?f 71gaM 7331 94e8-- QG(. 3000 None None Casing Length Size MD TVD Buret 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' 49801 4320 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 7132-7142,7155-7160, 6204-6212,8223.6243,6248- 2.876" J-55 7041' 7186-7190 r 6251 Packers and SSSV Type: Packer - Cameo HRP -1 -SP Packer Packers and SSSV MD (ft) and TVD (ft): MD = 7011 , TVD = 6106 and Cameo TRDP-IA-SSA safety VLV MD = 1800 TVD = 1800, 12. Attachments'. Proposal Summary 0 Wellbore schematic 1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service 14. Estimated Date 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 Contact Name: Hilaire Yerneli-Gozon Authorized Title: Petroleum Engineer Contact Email: hilaire.yemeli-gozon(d COP. cord (/ 0 0 Vr,(/ ZO/9 Contact Phone: (907) 265-1478 Authorized Signature: T Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 k -t - Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test d Location Clearance ❑ l F (ty I t� Other Post Initial Injection MIT Req'd? Yes No ❑ RBDMS JUN 1 6 2017 _ Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required. l G ij 0 /�/THEAPPROVEDY -/-Lf"_^�t',F+THE COMMISSION Dale: Approved by: /COMMISSIONER VTZ 4,/I -f/ trod 4/1/4- 7 Submit Farts end Fom f o-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Machrnents in Duplicate 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, t• f AIN 0 8 2017 AOGrj% 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 511, 1988 to January 14, 2016 when it was flow back operations started 7/14/2016 for reservoir pressure man 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 40 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 7 The top of the A sand was found at 7,126' M D / 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''/< 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 -I -SP Packer located at 7,011' MD (6,106' TVD) A State -witnessed MIT -IA will be performed once well 3M-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. • • Top of A. WELL Top of A-sand Sand Oil Top of Topa( Top of Cement Reservolr Zonal Cement Mechanical PTD API NAME STATUS Oil Pool AID) Pool Cemem Cement Determined By Status Isolation Operations Integrity (TVDSS) (MO) (TVDSS) Summary CAMCO2 16" Casing 198 sx 10/18/2016'. 7/8" HRP- CS II, 9-5/e" (WC) : MITOA Peds open 1-SP Retr. Casing 12005x C5 to 1800 psi 187-025 50-029-21706 3M-05 Producing 8664' 6165' 6200' 4604' CBL for Pkr 48K III &325 Sx Class (Passed). TIFL pull or Ret G, 300 Sx CS 11, 7" (Passed). production release Casing 400 Sx Initial TAIC,- 5.987" 00, Class G and 175 150/1275/122 2.347" 10 Sx CS I S. 12/21/2015: (Pre RWO) FT CBLTOC 16" Casing 200 sx LDST POT 7900'& CS It, 9-5/8" (PASS)7 Perfsopen Packer LD Casing 11105x C5 PPPOT(PASS) 187-040 50-029-21720 3M-13 Producing 9283' 6212' 7900' 5200' CBL for 9181'(less III&40DSx Class IC POT (PASS) production than200' G,7"Casing35O IC PPPOOA from top Sx Class G and (P ped) 1755x ASI 1800 PSI (PATS) Initial T/I/O =sl 16"Casing 200 sx 7/14/2016: C511, 9-5/e" Non- Perfsopen CAMCO Casing 1450 Sx AS witnessed MIT 187-053 50-029-21728 3M-16 Shut-In 7601' 6222' 4,900 3,762 CBL HRP-I-SP 111&400 Sx [lass IA Passed to for injection PACKER G, 7" Casing 300 1810 psi. Sx ClassG and Initial T/I/0= 175 Sx CSI 25/35/0 • • n ABL025522 X1 is ADLO25523 ADLO25512 13NR�$E ADLD2021 31 U Well Trajectory l WellN ConoeoPhillips Open Interval Alaska. Inc. Quarter Mile Open Interval Radius 3M-06 Wells within Open Interval Radius 0 0.2 0.4 Injection Swap Analysis u CPAI Leases lotiles Sf1812017 KUP PROD 3M-06 ConoeoPhillips ;, rIWSUAttributes IMSX Angle& MD ITU-- AWriG w•im.,. uwi visa wm• n wnieo,ane.. .all xo MK91 ea eon ln9e) LON0.uCiOR m. FRAC SLEEVE. .1911 VL 4u LY s9n:era..— YnCMfX:!OIeS— NIv L5, ) OMB 909; SW 1.3— TCNf; >,1990.1A. 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 '/. 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. MPK-17 1960280 980 TOC estimated at 4900' MD; Segmented Bond Log 1996 Table 1: Table showing distance & annulus integrity of wells within AOR Well Name Casing Hole Vol. of Kuparuk depth (MD) Kuparuk depth (TVDss) size Cement MPK-09 7" 8-3/4" 22 bbls 7200' 6734' - MPK-17 - 7" -8-1/2-- ---— 58 bbls - - - - - -- - 6887' - --- 6733' 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 i0"ITWI.w.F:T11 Ei JUL 2 5 2019 Y')r,In. r 1. Type of Request: Abandon Li Plug Perforations LJ Fracture Stimulate Li Repair Well Li Opemtions 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 ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ ElService ❑ 219-055-0 3. Address:Stratigraphic 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22419-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order go ms well spacing in this pool? N/A KRU 2E -17L2 Will planned perforations require a spacing a eption? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25658, ADL25665 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effectillip Depth MID Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,936' 6,109' 936 6109 3000psi Casing Length S e MD TVD Burst Collapse Conductor 80' 16' 121' 121' Surface 4,439' 9 5/8 4,481' , Production 9,164' 7" 82 6' 6, Liner 3,661' 2318 1 ,947' CIO' Perforation Depth MD (ft): Perforation Depth TVD (ft): bing Size: I Tubing Grade: Tubing MD (ft): N/A N/A 3.500" L-80 8,862' Packers and SSSV Type: Packets and SSSV MD (ft) and TVD (ft): PACKER -BAKER FHL PACKER Mona 8735 TVD=6014 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service O 14. Estimated Date for 8/15/2019 15. Well Status after proposed work: Commencing Operations: ❑ WINJ ❑� WDSPL El Suspended ❑ WAG ❑ GSTOR ❑ SPLUG \GS 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved here\will t bedeviated from without prior written approval. Authorized Name: Alex Trower Contact Name: Alex Trower Authorized Title: Sr. Petroleum Engineer Contact Email: Alex.J.Trower@cop.com Contact Phone: (907) 263-3733 Authorized Signature: Date: COMMISSION USE OIliL.Y Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Locatio Clearance ❑h/ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Form 10-003 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate M'0a u' k' ��o A'a 1 DL025656 2E s° ri1NR9E ii ADLo2sesa TiiNR DE� 110NR9E T10NR1OE t.'� ' % m zE.nu I AD ADL025660 Z K c � Rz N A 0 0.1 0.2 03 WMp4b eMO'n Imwi 111Ne —VMTgeelry O]EI]M INMI&hr —MK �.��0��)//y��E �3EI]OP^Mval a�1Rf tlIN41BWn PM�4 �K �LNLELAATEN��E-� �EE�I]LI(¢n NerM .R1R1PB1 a1NMi&lW -tlNM]Npnl IYW �3FI]I3 Qm Y1m1 ]EIRIPBRUIN M�Buh. OC4VImx 2E-77 �E-nuPel ox. nmw �xmzafa Mew., Injection Analysis �zEnuPela�M..w KUP IN ConocoPhillips Alaska, Inc. WELLNAME 2E-17 WELLBORE 2E-17 vEw,] I.g:u:n PM Last Tag .1. 0.) Annotation I Goodwill I Eng Oa@ walltOre LatMotl ey LA TTA,: 2E-1] 'lam all .................. .........._....._ HMGER: aG- _....... Last Rev Reason AnnetNon End OMeWellOole LmIMc4 By Rev Reason'. Dummy aft gas lift string 61192019 2E-17 Jaensen8 Casing Strings Lasing Description 00 (m 10 %I) Top (nKl3) &et Oeplx InKa) s Oegh (TVD)... MI -en 6... Topiareatl CONDUCTOR 16 15.06 41.5 121.0 121.0 62.58 rands40 WELDED Gahq Deaetlplbn I ED Ind 1 10 (in) T.W.) m.OeMt... I Sa, agars 1.nun . WIILen 11 1.1.0Top Th,W SURFACE 9518 892 41.5 4,4808 3,473.3 3600 755 BTC coxpuc]oR;usma2 casingDosaiplbn OD list10 (in) IT. WO) Set Moom(.a) eel OePth(NO)... WIILen 11...GMs Top Th,eand PRODUCTION ] 628 41.6 9,20]0 26.00 L-80 BTC -MOD Tubing Strings Tubing Descapron shine Ma... ID(In) mp ttxa) set 0"T (II_ set Wl (ont) Grade Top connection Gal UFT', Rena TUBING- 31/2 299 260 $861.8 61149 9.30 L-80 EUE8RM PRODUCTION Completion Details Top (DID) Top and Nominal Top hmag Mme) Than Ihn Dea Co. mpn) 26.0 26,0 0.00 HANGER Cameron CXS Tubing Hanger (] 1116• %312' EUE BRM BxP) 2.992 8,]186 6ON1 37.41 LOCATOR Locator Sub, Baker (3o spaceout) 2992 ZVRFeeb 41 E-tumi e- 8,7216 6003.5 3]40 SEALASSY Seal Assembly, Baker,B 2992 8,734.9 60140 3240 PACKER Baker ]"x3-12"FHLPa&er 2,992 GAS U11488B.2 B,]88.0 60562 37.34 UNDINU HES 3-12 x2.813" X Nipple Profile - 2,813 NIPPLE 8804.0 6,069. 37,37 OUTER WEDGE NOGaem Solutions 350.700 outer Waste 2,990 GAS LET, E.E 8818.1 6, 37.39 LANDING HES 3-11T x281 T X Ni,DD Pmlle- BakerlOCk 2.813 NIPPLE 8.8239 6.084,13 3239 OUTER -WEDGE Nmthem Solutions 350-700 Outer Wedge 2.990 8,837 9 6,095. 3].38 IANDIN HES 3-11] x 2,813'X Nipple Pm(he- Bakerack 2.813 GAe LPT251a5 NIPPLE 8.849.1 6,1 3].35 A I Trailblazer rasing scraper 2.510 SCRAPER 0.8600 61134 3233 FLOAT SHOE Fleet shoe 2.992 GAu LILT; B.YA3 Other In Hole (Wireline retrievable plugs, valves, pampa, Net, etc.) Toni Toimil Ml V) Gas Com Run DAh 10(In) 6,03.4 37.36 Fish Ilvak TDOrilling W In wrntl with" on 5rzaO9 TRACK BHA lop Gas uFT: e,mze 6,0714 3239 WHIPSTOCK o em oluliOn Fl Inner age W/ RA Tags9 51512019 tum top. DAL 12 max od 2.62Y r8,797 6.0802 3].39 X -Lock Flow 281"%Jock fiawwl fim Nm sub 515/2019 1]50 Thm Sub LowToa, e.vea 6.08)2 3].40 WHIPSTOCK o em Solution F/ Inner a ge l3 RA Tags S' 4512019SEAL ASSY em a agm Wp. OAL 12 max and 2.625" PACKER: 67GF.S 6.0962 37,30 X1ocIs Flow 2.81"X -lock fiowwlflons Nm sub 4141201 1]50 Thru Sub Mandrel Inserts 6t IANgNG NIPRE: B.]�90 an N Top "In Valve latah game TRO Run Top(KKB) (m(8) Make Muiel Grind_V2 8ery Tag, Thai (In) (W11 Run Gk Can 2,8]38 2,496.4 Camca MM 2 INJ DMY RK 0.000 00 611812019 2 4,8832 j .] Camca MMG 112 INJ DMY RK 0.000 00 611812019 3 6,4028 4,541.4 Camca MM 1112 INJ DMY RK 0000 0.0 611712019 DIRER wsDGE:aeoaa 4 ].518.5 5,202.0 Camm MMG 1112 INJ DMV RK 0000 0.0 1]2019 WHIPSTOCK a Amo 5 8,2293 5,650.0 CamCO MM 1112 INJ DMY RK 0000 0.0 IIII2019 6 8,6627 5,9563 Camco MMG 1112 INJ DMY RK 0.000 0.0 6']2019 UNOINGNIP%.E;aB1B1 %-Wck Fbx Thu Bub a0lBl Notes: General B Safety ErniDa@ An... 4212019 NOTES View Schema she w/ Alaska Schemaac100 CuTEHWEWE'.6.19.9 WHPSTOCK B,W0 FiNCTDCQLTRACKMuA; e,Twa X1ackFlw ThveW;6, IAXOIHG HIPPIE; B.83,�B CAamG$CRAPER.e,Ne.11 FLMiBXCE; B,Btla PRODUCTION; 41 a$b].a 1 KUP IN' WELLNAME 2E-17 WELLBORE 2E-171-2 101, Well Attribute Max Angl TD C�'--illi GielE Name 11212 APYUWI WeIIMeSlalue ncll°I MDIXKb� 4cl film lM1K01 Alaska,lOC KUPARUK RIVER UNIT 500292241961 INJ 960 9,140.81 12,9424 .11L2, 7RMA192 N M PY Last Tag ye My atllpnepc(ecpyl AnnWtlion OepM IKKB) EM Dale M01W. I Leet MOG BY LAST TAG: 2E -D12 lennalt Last Rev Reason ..................... .._...____. NnxGEa, a7.9- An�wbibn Ene Ole weuMrt Lem MaE By REV REASON: CID Latent 2E-1112 tennall leCasing Strings ds!OemOpfion JD 1I IO pm L2lATERAL IGTD) 2318 1.99 .;Irz%6) xl Devin lXKat 92fi.0 1$9474 so DePln OYol... wuLen O._Gnae 4.fi0 L-80 ruP rxrcaa STL Notes: General S Safety E^a oaN nneoeron iONDUCiORli 5izl:o 711012019 NOTE-. View Ecnematic Wl AI55k95chematic10.0 . IJFTZ.T EURFACE:4154,690.8� .UF1,e.099.i WS URI,, W IJFT;7,51e5 GOS LIFT; O.Zd.3 WO LIFT; O,t@.o LOCATOR: B,71B0 . ASSY. B,RI B PACIIER',8734.H LANDING NIPPLE: 0,7 .0 OUTER WEDGE 8 R.0 WHIPSTOCK0,M7.o LANDING NIPPLE; fl0 1&1 %-Ik Fb T 0W; 80191 ce OMER WEDGE: 90AH WHIPSTOCK 90 P.0 nn CTD COIL TRACKGNP: 0,7970 X -L FMT Nil, 0,097.0 IANOINGNIPPLE: 0,097.9 CFSI. SCRAPER: II..0 FLCATONOE: 8=0 1 1 1 PRODUCTION. 41.&9=0 I 13 UTEAAL(CTOII IZ.7,4 1z.9m4 2 190 55 30 99 7 Letter of Transmittal Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 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 -17L1 2E-17L1PB1 2E-17LPB2 2E-171-2 2E-17L2PB1 RECEIVE JUL 16 2019 AOGec (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 L Q Y I v L tQ O 0 NNQ I.L Q IA z a� tD V O `m , a �_ _ O t� LLIN *= OL Y Y N N V O 3 a 3 J a� O (6 V YYcmU) m W ■ tea! .. ■: . $Ga - - A �k� \12 2 �I;;li§ !!4j N IE: k!!§\ ( CL o 3/�)) )kk)/k - T-° ® !!! { „ . | 20. - k\x%77 » CL /!/ 0 C d E O O (� U' (7 (� (� () (� (� (� (� () f7 (� U' O O U' O U'U O O U' U' ❑ O (� (� (� (� 3330 0000»3 N3 3» 0 G❑ g 00 o0 0p0pp000 000p00 00000 00000 00000 0 0 000 p �p mNm rN O 0 PN 0O p0ry9m 0m M �2m 9 e nYI P ^ -N - .N m MQ 0 9 W m 0 m m Qm mN(Np . . m M M 9 l0 lm� 0mMA . 0 Z N YI VI N N 1N N 1t) YI 1N 10 YI N M 1N N N N N YI YI N N N N N M V1 N �(1 A U q O N L V V` J O C U O O o 1p P O 1p 1- Oi m r 9 N O Oi O) 1� n N N r C1 O 10 n n � O Cl O O Z N y O p ,g m m Ui6"1gga m e r' o 14i m Qm m e "' W CI Ci j U V M p� p m '° � rc 5ti 'y. 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F g ;u � n e n n fin' � m m o o s � � $N ry ry ❑ Q pp>> ❑ O 2 J 3 W; ui P P P P P < V Q Q P v a v$ Q Q V Q N N N M N N N N VI N VN J F g Z N❑ ; .. mm N� 0 11pp M tM�l � n M N 0p m b{p � � Mi � N r 0 0 0 b tMV 0 m 10 1p�p1 T � V p60�i pNp f 0Pp 0 f0 M C M n 10 O M N O� O W n M Nj �p Mp my O N O Y O M n Ji � 1C b Oi 1Qi m T N m Q�Q ,� 1 1 e m m m ❑j m O�i N OI O) ONi li Ti pi_ pi ({i_ N j F ap N N N M N N N N M N Va N N N N N 1�(0N N N 00y N N O �1ppp�� 0 � 1pN0� m 4 M n b O 1M0 � T O W n 1+1 N � G1 m 0, N N O Q O O ❑ pOH 1p 1On1pp MO MO q p� 0 q 0 0 101pp 0 0 0--- m O_ O m O O O J O O O O 0 0 0 0 ?- 10 1G •J tti 1G 1C 1G 1C 1C tD 1G tO 10 10 1ti 10 10 10 1ti 10 1ti 1D 10 1a N tG m t0 •ID N U C N N M ey N N OI N 1p � 1'1 N N S M Y 0 0 N O m M N a C N^ [p O O O ONI Q n 1D 0o 0 CI 10p� O 10 0 10 rt) f7 �2 V r w Vl L d Q Y N Y(pp N N p� pL ( 'Q' n p P �p M 10 11pp m M 11pp M p 10 N O Q 1p M CJ p 1p IO N p f0 pp n N 1p [0 p� 1M0 10 m N N O N O 4 6 W W W C W 1p p C M n 0 m 0 m 0 0 m M n W V m m 0 W W O OI f m m L iJ Y Y N N N 10 O1 O) M O+ M M M (G M M N m CL °i a m 9 n 0 m ua m m Q �0 G O 1N p 1hO V Oi 1Op Q O Q p O O O Q p m 0 p 0 0 0 0 0 t5 U d p O� d d G U n N ?i 3❑ N m S lei D0 g V m E a Z P O Q<< Q P P P O a SO SO SO SO SO 0 O SO 0 U O O O O O O O O O O O O O O OS OS p0 V O v S j d 01 T OI OI OI O1 T O1 N Or Oi T 6i T OI Os O Oi Oi N T 0 Oi T N N N 3 n n d O pp �1pp O A 0 0 N m r N v . 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To Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 219U55 30996 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue 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 RECEIVEt) JUL 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 C@BakerHughes.com i LO Lf) to C:) cn rn cn P Q CV M EM) W� E MW m i L Q Y v Q m LLJ Q N Z Q .— � � d V O a _ O v �Nma += i O Y Y N N V O L M c.a7o LJ� f6 t` N (� _ �• U Ye i Lo m 0 m Z 3 m D 0 2 m � N _ ^ m O o m y�jU'S h 4 m c^V O £ d o O T U m c O N fL = J a E U U' J N ^ a Z O ❑ 9 m I n E ? 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Y z j• �o ro e N m c5 16 to . to to to . to to ro �c �c ro to (c ro to ro m �o �ti ti ro to to V C 0 Y Q c y� p p 1p Ip N � - m - - f - - m m - - - - - - - `a N a ary 1/1 H m P N N n R f0 N O O H M 0 R N N m N o>> W W W _ m m m m m `m m m m S. m m m m . m m m Nm `� m o L U Y Y N N N m mP m m m m m m _ 0 0. p N m FC Z H mQ ry Ty Npp m,Q pm m V O H OP n � p T ❑ m M U d N ?i �i ❑ N I 0 m a' N M T # §{{ E< ,/\\!|j eCL 2®� \\ \|■) � \ -��/}) #«\\ J!! ¥! 7k�(� } . L 2 Lb b 00 NN --�- ® � : ( G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION JUL C 1 2019 WELL COMPLETION OR RECOMPLETION REPORT AND- CC 1a. Well Status: Oil ❑� • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WIND❑ WAGE] WDSPL❑ No. of Completions: 1b. Well Class: Development E] • Exploratory ❑ Service El Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abard.: 6/1/2019 14. Permit to Drill Number / Sundry: 219-055 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 518/2019 15. API Number: 50-029-22419-61-00 4a. Location of Well (Governmental Section): Surface: 642' FSL, 160' FWL, Sec 36, T11N, R9E, UM Top of Productive Interval: 1281' FSL, 1709' FEL, Sec 1, T10N, R9E, UM Total Depth: 1739' FNL, 850' FWL, Sec 7, T10N, R10E, UM 8. Date TO Reached: 6/16/2019 16. Well Name and Number: KRU 2E-17L212E-17L2P81 9. Ref Elevations: KBA46 GL: 105 BF: 17. Field / Pool(s): , Kuparuk River Field/Kuparuk River Oil 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: ADL 25658, ADL 25664, ADL 25665 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 529971 y- 5944285 • Zone- 4 TPI: x- 533404 y- 5939639 Zone- 4 Total Depth: x- 535976 y- 5936651 Zone- 4 11. Total Depth MDITVD: • 12936/6109 ' 19. DNR Approval Number: LONS 84-029 12. SSSV Depth MDrrVD: N/A 20. Thickness of Permafrost MD/TVD: 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: 1 NIA (ft MSL) 21. Re-drill/Lateral Top Window MDrrVD: ' 8807/6071 ' 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 WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H40 41 121 41 121 24 200sx CMT 95/8 36 J-55 41 4481 41 3473 12.25 800sx 11.0 AS III, 600SX Class G 7 26 L-80 31 9196 31 6380 8.5 275sx Class G 23/8 4.6 L-80 9286 12936 6094 6109 3 Slotted Liner 24. Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner@: 9295-11420 MD and 6092-6093 TVD 11436-12936 MD and 6093-6109 TVD COMPLETION Y % E 1 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 112 8862 1 873516014 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) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): UNABLE TO PRE -PRODUCE AS PLANNED Date of Test: Hours Tested: Production for Test Periotl Oil -Bbl: Gas -MCF: Water-Bbl:Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I Calculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water-Bbi: Oil Gravity - API (corr): Form 10-407 Revised 512017 VTL r9�3I / /m /r CONTINUED ON PAGE 2 RBDMS� JUL 0 8 20195 b� RIGI IAL only!L^ _I � llr� 28. CORE DATA Conventional Core(s): Yes ❑ No D Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, Fromrro), 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 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C4 8807 6071 2E-17L2PB1 TPI 11281 6096 TO 12537 6102 / TD 12936 6109 Formation at total de the Kuparuk 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, paleontoloaical report, production or well test results. per 20 AAC 2&070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James -64i' r '+( Contact Name: Ryan McLau hli Authorized Title: er- G%% Contact Email: an.mclau hlin co p.com Authorized Contact Phone: 265-6218 Signature: Date: _ 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 41b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 3E47Currtnt Sche tic d18'38#}Mshoe 4W1 -MD aoPBMin Em 0 maOtl BWi'Mp 2eB Lap.k..o MES ND 112' 8.3d 1-80 ELIE BN Tubin0 he spread, 3-12' Carecu MAG gas SB mandrels @ 2074', 4803'. WS, 7519'. 8228', MT RKB Baker Lacaer@ 8]vWE(3' staceou) Baker PER BBdO@ V] MDWID) Baker FHL Pecker@ EMS MD (4' ID) 3 -lo -x mine, nipple at 87B8'MD (2.813' pan ID) Northern BoluBons WEDGE had. deUik) Top of Wadga RseembN@8]BB'POC }%' %lending ahold N 8818MD (2.813' - ID) 3-K" %landing nipple at 8838' MD (2 013' nan IDI Treilbbzer casing scraper@ BMW MD Fear Shoo @ 8860' MD Northern S,hadca s Vlsdg. 3-12' am "0 B. Pipe 5. V011(12.9'eng) 'o635°ewe ndUppe i�av� 1.125• Bar. sup Lwve, Bodeen fi13PBt oDaa Ai �11.aR np, 1,.". 1 AT W KUP PROD WELLNAME 2E-17 WELLBORE 2E-17 CorxxxiPhWell AHnbut Max Angle 3 TD (��(p5 FleleName WeIIEo,eFPYVWI WeIIW,eSlalus ncll'I MO (h p[IB1m111%0) Alaska. Ina KUPARUK RIVER UNIT 500292241900 PROD 600 6.16233 92060 SSSV: NONE I I I LAST WO. 3/242019 141.50 2E-17.7n7A1510'.07:50AM Last Tag eeee„alsdwr¢B examen Annolareen Ilepthabse End pad, I Welton I east MeesY LAST TAG 2E-17 'Barash xnxLEa, xio_ Last Rev Reason A......in End pan, I W¢IICo,a I Laet Mad By Rev Reason'. Dummy off gas lift string IsnOceulia ", Jllanseed Casing Strings Laine Ore'"Pen toi(m) What Tol,bri Set Depth MIKA) Set Gaper D' .. WVLen N-. sine Tap Thee CONDUCTOR 16 1506 41.5 1210 121.0 6258 H40 WELDED Buse. Oeecdphon OD Dp IDand Top(KKe) 8¢I pepN, ptl(BI Set paper IM11.. Veto- L_Grave TapI nand SURFACE 95/8 892 41.5 4,480.8 3,473.3 DODO J-55 BTC ��CONDUGTOF: et'S1RI0 Gsk,p Dakllpat OD(I.I ID 6,o Topprien SSI DepM MKID Se Depth jNDl... Wi (I...ai Top TaW PRODUCTION 7 6.28 416 9,20].0 26.00 L-30 BUT Ceel,p peu,iPlion ODlinl ID llnl Top IOMBI $e10¢p1A IflaB) SM DePIx (ND/... WIM1en 11...GMe TDp ThIW Ged"Er:zose L2 IATERAL(CTII) 2311 1.99 9,286.0 12,947.4 460 L80 STL Tubing Strings Tuhae Dee[npelon smog Ma... Wpn) Top Me) xL oeptn m..setin (rvDI(...vApnrq Gaee TopConnec- TUBING- 3V2 299 26.0 8,861.8 61149 9.30 L-80 EUEBRM PRODUCTION Completion Details SVRFACE;415-4,48(i Top IND) Topin[I Nominal Top lnnel Me) rl Lem Des Com in (m) 2(0 26.0 000 HANGER Cameron CXS Tubing Hanger (7 TITY x 31/2-EUE BRM BxP) 2.992 GAS UFT; 4.8-tl.2 8,718.6 6,001.1 3741 LOCATOR LocaWr Sub, Baker (-3'.1$Pat.,) 2.992 8,721.6 6,003.5 3740 SEALASSY Seal Assembly, Baker, 00-00 2.992 8,734.9 6,014.0 3740 PACKER Baker T 3-1/2"FHL Packer 1992 ws um:e,4oza 6788.0 6,056.2 3].34 LANDIN HES 3-1 'x2813 -X Nipple Prefile 2.813 NIPPLE 6804.0 6,0690 3137 OUTER WEDGE Nodhem Solutions 3501 Outer Wedge 2990 Goa LIFT', 7,5185 1,8181 6.080.2 37.39 LANDIN HES 3-112°x2.813"XNipple PraGle-BaMi 2.813 NIPPLE ,8239 6.084.8 3139 OUTER WEDGE NONinve Solui 350.700 Outer Wedge 2.990 GeB UFT:aZ®.S 6837. 6,095.9 3738 LANDING HES 3-112" x 2.813' X Nipple Profile - Baketlock 2.813 NIPPLE 8,649.1 6,1048 37.35 A ING Trailblazer casing scraper 2.510 SCRAPER fins LIFT', earn 8,860.0 6,1134 3].33 1 FLOAT SHOE Float shoe 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ,up (We) Topincl Top OMB) (MOD I-) One Com Ran Dace 10 (in) LDwT A7la.a 8,79]0 6.0634 3736 Fish TDCOIL Codeak CTD drilling BHA, tuck in window With T Ton 512312019 sEu pxc:e,rn.e TRACK BHA lop PAGKER:AID4.B 68070 6,0714 3138 WHIPSTOCK 70MITern ouban I Inner Wedge W/3 RA Tags S' 992019 from top. OAL 1T max od 2.625" 1,818.1 6,0802 3].39 X -1 -rack 2.81"X- kfiowwl8pwthrusub 992019 1.750 Thal Sub LAHDFIGNIPPLEil Mia 1,8270 6,0812 3740 WHIPSTOCK o em pINOn / Inner Wedge WI 3 RA Tags 5' 4192019 _77310 been tpp. DAL 1T Max M 2.625" 6,0952 3738 X -Lock Flow .1 -X -lock flow ed/fi9w Nm sub 4/42019 1.750 Thru Sub WTERWEDGE;4BM0 Mandrel inserts a1 WXIPBTpre"BT.O a IANDIxO NIPPLE: %-LW Ebxil,ru SW; 0.9191 N Top(TVD) Veva Lambe Part6ee TRO Run Top MM 181(6) Mand Model Oli Sery Typ Type (In) (pal) Run band Lom 2,87.1 2.496.4 Cameo MMG 1112 GAS LIFT DMV RK DOW OD 61182019 2 4,8832 3,7067 Cameo MMG 1112 AB LIFT DMY RK 0.000 -6-4'U8 011 61182019 3 4,541.4 Cam. MMG 1 l2 GAS LIFT DMV RK 0.000 011 rv/172019 WTERWEDGE 0.020.8 4 7,518.5 52020 Cam. MMG 112 GAS LIFT DMY RK 0.000 0.0 611]2019 dnlps7oce.expa 5 8,229.3 5,650.0 Cameo MMG 1112 GAS LIFT DMY RK coo 0.0 611]12019 Fhh CTDCCx THAod Igh A; 8. 6 0 6 66227 5,9567 Carrico MMG 11/2 GAS LIFT DMY RK 0000 0.0 6/1712019 Notes: General & Safety x.L:k FI>.TNus.N9sa7o VNOING NIPRE; 9,W7B End Oe4 Annotation CASINGaLRAPEk,a9w0 42/2019 NOTE'. View Schematic W/ Alaska ScremallClD.B FLCATSHCE,8e600 I I I MOWCTON, 4169,W70 II ) II U.I.RALICTOk8.2M.D� Madre r Uperations Summary (with Timelog Vepths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time our (hr) Phase Op Cod. Adivity Cade Time P -T -X Operation (fiKB) End Depth (RKB) 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. R/D cellar 4/29/2019 4/29/2019 6.50 DEMOB MOVE DMOB P Complete cellar R/D, 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 07:00 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 14:00 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 hard) -line, begin NU BOPE, continue BOP re-config 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 0000 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 0 rings, 0.0 0.0 00:00 0230 Grease crew here to service tree. Grease all valves 4/30/2019 4/30/2019 0.50 MIRU WHDBOP BOPE P PJSM for BOPE lest. Go over new 0.0 0.0 02:30 0300 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 Edina, 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 22:54 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 2306 line, clear floor 4/30/2019 5/1/2019 0.90 PROD1 WHPST PULD P PJSM discuss new PD checklist, load 0.0 0.0 23:06 0000 PDL, begin PD BHA#1 Window 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 PROD1 WHPST PULD P Complete PD BHA#1 Wiindow 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 5019 1.80 PROD1 WHPST TRIP P RIH w/ BHA #1 77.0 8,745.0 0118 03:06 Page 1/34 Report Printed: 7/1/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DepM Start Time End Time Our h (p Phage O Code p A vi Cade ty Time P -T- X OpereGon (flKe) End Depm (flKe) 5/1/2019 5/1/2019 0.20 PROD? 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 8,826.6 04:18 04:30 at 8827', PUW = 31 K, come up to 1.8 bpm 5/1/2019 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 511/2019 5/1/2019 2.50 PROD1 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 512/2019 1.00 PROD1 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 PRODt 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 5/212019 2.00 PRODi 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 5/212019 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 5/2/2019 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 off. Time mill for string reamer exit 5/2/2019 5/2/2019 0.80 PROD1 WHPST WPST P 6836 Milling rathole, 1.76 BPM @ 6,836.0 8,845.0 07:00 07:48 3755 PSI FS 5/2/2019 5/212019 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 512/2019 1.50 PROD1 WHPST TRIP P 8842', Trip for build section BHA, 8,842.0 77.0 09:24 10:54 PUW=28K 512/2019 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 5/2/2019 5/2/2019 0.70 PRODi DRILL OTHR P M/U no=le slab on well. Jet stack 0.0 0.0 12:00 12:42 flush surface lines of metal 5/2/2019 51212019 0.80 PRODi 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 ON and surface test 5/2/2019 5/2/2019 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 K1 for 4 correction, PUW=30K 8,735.0 8,770.0 15:48 15:54 5/2/2019 5/2/2019 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 PROD? DRILL DRLG P 8845', Drill 1.86 BPM @ 3530 PSI FS, 8,845.0 8,874.0 16:06 1648 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: 71112019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time I End Time DW (hr) Phase op ccae Activity Code Time P -T -x Stan DepDepthape�ation n De End Depth (flKa) 5/2/2019 5/2/2019 0.50 PROD1 DRILL DRLG T Became 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 PRODi 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, tum odenter clockwise & work pipe, unsuccessful, rotate hot counter clockwise, work pipe, unsuccessful Begin working pipe down, 5/2/2019 5/212019 1.50 PRODt 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 5/2/2019 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) 5/2/2019 5/2/2019 0.60 PROD1 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 5/212019 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 PROD? DRILL TRIP T RIH w/ BHA#3 200.0 8,745.0 00:00 01:30 513/2019 5/3/2019 0.10 PROD? DRILL DLOG T PUW =29K, log K1 for -11.5' 8,745.0 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 PROD1 DRILL TRIP T Begin jarring down, broke free on 4th 8,874.0 8,874.0 01:42 02:00 jar lick, RIH to 8782', stack weight 513/2019 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 PRODt DRILL CIRC T Displace well to 11.5 ppg KWF & 8,732.0 65.0 03:18 05:18 POOH 5/3/2019 5/3/2019 0.70 PRODi DRILL PULD T At surface, PJSM, flow check well. Lay 65.0 0.0 05:18 06:00 down tools on dead well. All fish recovered 5/3/2019 5/312019 1.20 PRODt DRILL PULD T Make up BHA #4,1' aKO motor and 0.0 62.7 06:00 07:12 1 I I 2.80 Crayola mill to dress window 5/3/2019 5/3/2019 1.20 PROD1 DRILL TRIP T RIH BHA 94. Pull BHA out of hole to 62.7 62.7 07:12 08:24 adjust wear band on motor Page 3134 Report Printed: 7/1/2019 P Uperations Summary (with Timelog Depths) + r' . 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (flKB) 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 PRODi DRILL DLOG T Log 1 for -12' correcion 8,740.0 8,764.0 10:06 1012 5/3/2019 5/3/2019 0.70 PROD1 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 1248 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 5/3/2019 5/3/2019 1.60 PRODi DRILL REAM T 8832.3 first time making it back to 8,832.3 8,830.0 1248 14.24 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 WHIP. Pressure up on well. Ramping pump up. Dumping pump 5/3/2019 5/3/2019 0.10 PROD1 DRILL OTHR T Go to neutral weight, 15 ROHS, 8,830.0 8,812.0 14:24 14:30 release from coiltrak, 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 PROD? 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 1736 (Accelerator, weight bars, & up/down jars) 5/3/2019 5/3/2019 1.70 PROD? 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 5/3/2019 5/3/2019 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 PROD? DRILL JAR T Begin jarring down, 12 licks down, fish 8,783.0 8,783.0 22:00 2242 is free on 12th lick 5/3/2019 5/4/2019 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 5/4/2019 1.20 PROD1 DRILL PULD T PJSM, flow check, LD BHA #5 & fish 69.0 0.0 00:24 01:36 5/4/2019 5/4/2019 3.40 PROD? 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 0500 06:18 drill/brush run 5/4/2019 5/4/2019 2.00 PRODt DRILL SLKL P Trip in with wire brush on slick line to 0.0 0.0 06:18 0818 brush profile in tandum wedge Page 4134 Report Printed: 7/112019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DepN start Tune End Time du (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depm (ftKa) 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 PROD1 DRILL SLKL P On surface. Still have plug on Mine, 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. M/U redressed flow through X -lock. Trip in and set @ 8809 SLIM. 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 1 1 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 nozzle, 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 1 1 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 wl BHA #6 74.0 8,750.0 00:00 01:18 5/52019 5/5/2019 0.10 PROD2 RPEQPT DLOG P Log K1 for -125, PUW = 30K 8,750.0 8,785.0 01:18 01:24 5/52019 5/52019 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 5/52019 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 5/52019 5/52019 3.30 PROD2 RPEQPT SLKL T PJSM, RU slick -line 0.0 0.0 04:36 07:54 5/52019 5/52019 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 5/52019 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 dg down slick line unit 5/52019 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 1642 5/5/2019 5/52019 0.10 PROD2 RPEQPT DLOG T Log Kl for -1 Tic, 8775.47, PUW=31K 8,750.0 8,788.0 16:42 16:48 Page 5134 Report Printed: 7/112019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Mot Depth Sort Time EW Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (flKB) End Dept)(W) 5/5/2019 5/5/2019 0.30 PROD2 RPEQPT TRIP T Continue in set @ 8819, 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 5/5/2019 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 5/5/2019 5/5/2019 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 5/612019 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, dp = 928 psi, avg ROP = 0.4 fph 5/6/2019 5/6/2019 2.00 PROD2 WHPST WPST P Milling, CWT = 11.9K, pump = 3949 6,809.0 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 8,810.6 04:00 05:00 psi, WOB = 3.4K, dp = 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 pump = 4100 psi, FS = 675 psi 5/6/2019 5/6/2019 2.80 PROD2 WHPST WPST P PIU 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 5/612019 5/6/2019 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 516/2019 5/6/2019 0.70 PROD2 WHPST PULD T M/U RB WFT.4° fixed bend motor 0.0 65.0 20:00 20:42 with new short shank NS Mill and deploy BHA#9 5/6/2019 5/6/2019 2.40 PROD2 WHPST PULD T Laying down motor started 65.0 0.5- 20:42 23:06 investigateing 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 1 I Inteq A*Motor 5/7/2019 5/7/2019 1.60 PROD2 WHPST TRIP T RIH w/BHA #9 63.0 8,735.0 00:00 01:36 I I 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: 71112019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Start Time End Time Dur (hr) Phase Op cede Achviy Code Time P -T -X Operation (WS) End Depth (flKe) 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 5/712019 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 0400 0530 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 517/2019 517/2019 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 5/7/2019 0.50 PROD2 WHPST CIRC P Swap out counter, resolve issue, log 8,800.0 8,832.0 07:18 07:48 K1 for+0.5' correction, RBIH to continue reaming 5/7/2019 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 PRO02 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 1 1 Igo 5/7/2019 5/72019 0.50 PROD2 WHPST BOPE P Function test BOP's, PU & LD test jnts 0.0 0.0 11:42 12:12 5/7/2019 5/7/2019 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 can, check pack -offs, MU to coil, set counters. Mill in at 2.79" NG 5/7/2019 5/712019 1.70 PROD2 WHPST TRIP P RIH w/BHA #10 62.0 8,735.0 13:06 14:48 5/7/2019 5/7/2019 0.10 PROD2 WHPST DLOG P Log Kt for+2.5', PUW = 30K, close 8,735.0 8,766.0 14:48 14:54 1 1 1 EDC 5/7/2019 517/2019 0.10 PROD2 WHPST TRIP P Continue RIH 8,766.0 8,005.0 14:54 15:00 517/2019 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 - clean 5172019 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 5/7/2019 0.50 PROD2 DRILL CIRC P Stab injector and jet slack. 0.0 0.0 20:36 21:06 5/7/2019 5/72019 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 5/72019 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. 5/712019 5/8/2019 0.10 PROD2 DRILL DLOG P Tie into the K1 for a +2' correction. 8,730.0 8,761.0 23:54 00:00 Page 7134 Report Printed: 7/12019 Clperations 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 Activity Code Time P -T -X Operation (RKB) End Depth (MB) 5/8/2019 5/8/2019 0.50 PROD2 DRILL DISP P PU Wt 31 k continue to turn 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 5/8/2019 0.10 PROD2 DRILL TRIP P S/D 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 Wts 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 06:12 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 & dear MM 5/8/2019 5/8/2019 0.10 PROD2 DRILL DLOG P Log K1 for 0' 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 5/812019 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 = 11.3K, 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 = 2.3K, 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, tum into BHA wiper 5/8/2019 5/8/2019 0.20 PROD2 DRILL WPRT P Difficulty getting started drilling, PLI, 9,110.0 9,110.0 14:48 15:00 dp 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 5/812019 5/8/2019 4.00 PROD2 DRILL DRLG P Drilling, CWT= 11.6K, WOB= 1.2K, 9,110.0 9.330.0 15:00 19:00 pump = 4689 psi, dp = 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 I I 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 1 Page 8134 Report Printed: 7/112019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stem DePth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation 0") End Depth (KKB) 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 it/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 @ 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 W133 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/ TF, 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 W19.1 k lbs, WOB 2 k lbs, ROP 81 ft/hr 5/9/2019 5/9/2019 0.50 PRO02 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 PROD2 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 @ 1.8 bpm, 10,130.0 10,200.0 07:06 08:00 CWT = 4684 psi, WOB = 1.21K, 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 MOB (will raise rate once dropping) 5/9/2019 5/9/2019 1.40 PROD2 DRILL DRLG P MM packing off, bypass & blow down, 10,200.0 10,282.0 08:00 0924 still packed off, snake MM Drilling, CWT = 6.5K, WOB = 1.81K, 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 12:54 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 = 10K 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, WHP = 120 psi, pump 4900 psi, lower ROP over interval Stalled at 10,542', PUW = 34K Page 9134 ReportPrinted: 711/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Aceviy Coe Time P -T -X Operation San Depth (fIKB) End Depth (ftKB) 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 31k 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 tU min " New mud at the bit 10,730' 5/9/2019 5/9/2019 0.40 PROD2 DRILL WPRT P Wiper up -hole, PLOW = 33K - pulled 10,861.0 10,000.0 20:00 20:24 early due to close approach to south west comer of the polygon. 5/9/2019 5/9/2019 0.40 PROD2 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 oQ 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 Ibs. 10939' PU Wt 32 k lbs 10969' PU W134 k lbs 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 Ibs, WOB 2.8 k lbs. ROP 70 ft/hr Added 1% screen clean to High and low vis sweeps, no improvement in ROP noticed. 5/10/2019 5/10/2019 0.90 PROM DRILL WPRT P PU Wt 33 k lbs, Wiper#3, longwiper to 11,260.0 8,830.0 02:54 03:48 the Kt for tie in. 5/10/2019 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 Ibs- 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 loVis sweeps at bit at 11,430', no noticeable improvement w/ SkreenKleen coming around Difficulty drilling at 11,451', WOB stacking, PUW = 31K 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: 7/1/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sbn Time End Tinge Dur(hr) Phase Op Code Adivity Code Time P -T -X Operabon Start Depm (111(13) End De" (M(8) 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 12:18 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 = 10K, 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 1400 CWT = 8.8K, WOB = 1.5K, annular = 3843 psi, WHP = 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 to taget 86° 5/10/2019 5/10/2019 3.00 PROD2 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 rate & 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 PROD2 DRILL TRIP T POOH open hole chasing sweeps, 11,606.0 8,787.0 18:06 19:12 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 billow 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 his, NOV agitator. Skid cart, slab 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, dose EDC @ 500', shallow test 72.0 3,270.0 23:18 00:00 agitator, 1021 psi @ 1.8 bpm, continue in hole. 5/11/2019 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+1.5' 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'. Pi 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: 711/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stare Depth Stan Tme End Time our (hr) phase Op Code Activity Code Time P-T-X Operation (MB) End Depth (MB) 5/11/2019 5/11/2019 2.50 PROD2 DRILL DRLG T CT 4640 psi, @ 1.67 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 Ibs, WOB 1.1 k lbs. 5/11/2019 5/11/2019 2.00 PROD2 DRILL DRLG T Drilling, continuous rotation when 12,052.0 12,166.0 05:00 07:00 possible, CWT = 0.3K, WOB = 1.2K, annular = 3947 psi, WHP = 56 psi, pump = 4907 psi, begin catching samples again at 12,100' pertown geology, cutting ratio = 1.56 5/11/2019 1.30 PROM DRILL DRLG T Drilling, CWT=-2.8K, WOB =1K, 12,166.0 12,230.0 07:00 15/11/2019 08:18 annular = 3934 psi, pump = 4938 psi, struggling w/ weight transfer, pump 5x5 sweeps 5/11/2019 5111/2019 0.40 PROM 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' 5111/2019 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 rale 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 5111/2019 1.10 PROD2 DRILL DRLG T Drilling, FS = 1025 psi @ 1.9 bpm, 12,230.0 12,297.0 09:12 10:18 CWT = 1.5K, WOB = 1 K, annular = 3960 psi, WHP = 30 psi " PJSM, begin dropping DS PDS to send in for inspection, change out pack-off. 5/11/2019 5111/2019 3.20 PROD2 DRILL DRLG 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" mc), 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 1724 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 open EDC, online @ 2 bpm, 7,365.0 66.0 19:18 21:06 H. s at the shaker- started showng 154, 1600' bit depth, RBIH jog, pump p hole timing sweeps out, s cleaned up PUH bump up Page 12134 Report Printed: 711/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time EM Time our (hr) Phase Op Code Activity GDda Time P-T-X Operation (WEI) Erie Depth (flK8) 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 Kt 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 8,768.0 11,331.5 01:18 0218 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, starting 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 PROD2 STK TRIP T Continue to POOH 8,648.0 72.0 03:30 04:54 5/12/2019 511212019 1.40 PROD2 STK PULD T PUD BHA #14, anchored billet setting 72.0 0.0 04:54 06:18 assembly. 5/12/2019 5/1212019 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 cold, tag up, space out, set counters 5/12/2019 5/12/2019 1.70 PROD2 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 5/1212019 5/12/2019 0.10 PROD2 STK DLOG T Log Kt for 4.5' correction 8,740.0 8,773.0 09:18 09:24 5112/2019 5/12/2019 1.00 PROD2 STK TRIP T Continue RIH, clean through widnow, 6,773.0 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 12:42 5/1212019 5/12/2019 0.30 PROD2 STK KOST T 3 fph for 1 foot 11,322.3 11,323.3 12:42 13:00 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 14:12 11,329.3', PUW = 36K, stall again at 11,328.6'& 11,328.5', PUW = 35K Page 13/34 Report Printed: 7/1/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Steri Depth Start Time End Time our (Irn Phase Op Code AAVdy Code Time P -T -X Opereson (RKB) End Depth (NS) 5/12/2019 5/12/2019 2.30 PROD2 STK KOST T Confer with town, decision matle to 11,329.3 11,329.0 1412 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 PROW 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 PROM STK TRIP T RIH to clean up cased hole after 4,974.0 7,586.0 19:12 19:36 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 PROM STK PULD T Skid cart, jet stack, pop off. 0.0 0.0 23:24 23:48 5/1212019 5/13/2019 0.20 PROM 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 PROM STK PULD T Continue PD BHA# 16, second 0.0 70.0 0000 01:00 attempt, aluminum billet with open hole anchors. Skid cart, 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 0254 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 PROM 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 PROM STK TRIP T Continue to RIH. 8,830.0 11,293.9 03:18 04:06 5/1312019 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 5/1312019 5/13/2019 1.60 PROD2 STK CTOP T Pulll checks, MU nozzle, stab on, roll 0.0 0.0 08:06 09:42 coil to fresh water, flush slack & 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 10:00 1 psi low/ 3800 psi high) Page 14134 Report Printed: 711/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth start Time End Time our (m) Phase Op Cade Activity Code Time P-T-x Operation (a(e) End Depm(flK0) 5/13/2019 5/13/2019 1.50 PROD2 WHDBOP CTOP T Unstab injector, break off nozzle, Gear 0.0 0.0 10:00 11:30 floor, grease Romeo's R Bravo's, fluid pack, line up valves " ODS PDL pre-loaded 5/13/2019 5/13/2019 2.70 PROD2 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 PROD2 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 PROM 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 5/13/2019 1.90 PROD2 WHDBOP ROPE T Complet BOP test- 0.0 0.0 16:36 18:30 1 1 ' 7 hr test 5/13/2019 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 HS 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 11,2811. 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 125471bs.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 fl/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 lbs. Chase 11,285.0 11,292.0 02:18 02:24 ROP up to 90 ft/hr to catch WOB. 6/14/2019 5/14/2019 2.70 PROD2 DRILL DRLG T Drilling 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 Ibs. Drill to 11,325', PU 33 k lbs, PUH through billet - clean. RBIH, dry drift billet - clean. BOBD. - New mud to su face 5/14/2019 5/14/2019 3.30 PROD2 DRILL DRLG T Drilling, CWT= 1.51K, 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 PROM DRILL WPRT T Wiper up-hole, PUW = 35K 11,700.0 10,900.0 08:24 08:42 1 Page 15/34 Report Printed: 7/1/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (Inn Phase Op Code Ac Wy Cale Time P -T -X Operation (11KB) End Depth (fiKB) 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 = 5.8K, WOB = 1 AK, annular = 3815 psi, WHP = 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 fph 5114/2019 5/14/2019 1.50 PROM 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), PUW = 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 PROM 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 = 4.6K, WOB = 1.4K, annular = 3892 psi, WHP = 50 psi, pump = 4848 psi, MM out drive gain percentage dirty, bypass & blow -down, PUW = 39K from 12,255', avg ROP = 57 fph 5/14/2019 5/14/2019 3.90 PROD2 DRILL DRLG T Drilling, CWT = 1.4K, WOB 1.7K, 12,255.0 12,469.0 19:42 23:36 annular = 3878 psi, pump = 4877 psi 5/14/2019 5115/2019 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 8,630.0 00:24 02:00 to the window for tie in. Pull neg WOB and Ct Wt overpulls at 9068 - 8977'. Jog hole to 8986 PUH to 8933 Jog to 9079' PUH, Bottoms up from trouble spot unloaded a Iargee amout of very fine cuttings. no rocks. 5/15/2019 5/15/2019 0.20 PROD2 DRILL DLOG T Tie int othe RA lag 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. S/D 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 Itis Page 16134 Report Printed: 711/2019 a 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 Cods Activity Code Time P -T -X OpersUon (NCB) End Depth (ftKB) 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 11/hr 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 k lbs, BHP 3958 psi. ROP = 37 ft/hr 5/15/2019 5/15/2019 3.00 PROD2 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 = ft/hr 5/15/2019 5/15/2019 0.40 PROD2 DRILL WPRT P PU Wt 36 k lbs PUH on 1000' 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 PROD2 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 1 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 1 liner running pill,and KW. 5/16/2019 5/16/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for -4.5' conctio. 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 obsem build and stabilize at 3577 psi over 30 min. BHP 11.41 ppg EMW 5/16/2019 5/16/2019 1.50 PROD2 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'- 6/16/2019 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: 71112019 Uperations 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 Corte ActMty Cafe Time P -T -X CperaEon (ftKB) End DePO (WB) 5/16/2019 5/16/2019 0.30 PROD2 DRILL DISP P Turn the coil over to 11.6+wieighte 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 nozzle @ 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 13:36 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 13:36 14:54 the catch drum on the floor - Flow check - Good LD BHA # 17 over a dead well. 5/16/2019 5/16/2019 0.50 COMPZ2 CASING PUTS P Prep floor to start picking up liner. 0.0 0.0 14:54 15:24 5/16/2019 5/16/2019 3.00 COMPZ2 CASING PUTS 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 COMPZ2 CASING PULD P PJSM, PU/MU CoilTrak tools with 1,512.7 1,556.9 18:24 18:54 BOT 3" GS spear 5116/2019 5/16/2019 1.50 COMPZ2 CASING RUNL P RIH 1,556.9 8,765.9 18:54 20:24 5116/2019 5/16/2019 0.20 COMPZ2 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 COMPZ2 CASING RUNL P Continue IH 8,756.7 12,950.0 20:36 21:42 5/16/2019 5/16/2019 0.20 COMPZ2 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, Diff --961, PUW 32 k, DHWOB=0.6k, remove liner length from counters, line up across the top 5/16/2019 5/1612019 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 Kt 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 COMPZ2 CASING TRIP P Continue POOH 3,428.0 44.2 00:00 00:36 5/17/2019 5/17/2019 0.50 COMPZ2 CASING OWFF P At surface, montior well for flow, PSJM 44.2 44.2 00:36 01:06 5/17/2019 5117/2019 0.50 COMM 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 COMPZ2 CASING PUTS P Prep RF for Liner OPS, PJSM 0.0 0.0 01:51 0209 5/17/2019 5/17/2019 3.40 COMM CASING PUTS 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 5/1712019 5/17/2019 1.00 COMPZ2 CASING RUNL P RIH 2,192.0 8,700.1 06:21 07:21 Page 18/34 Report Printed: 711/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start7me Erb Time Dur(m) Phase op Code Activity Code Time P -T -X operation (ttKB) Ed Depth(fiKB) 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 Ibs -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 K1 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 k, SID 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. 5117/2019 5/17/2019 1.90 PRODS 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 dg 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 gel 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 Ki 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 - close EDC 5/17/2019 5/1712019 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 5/1712019 5/17/2019 0.70 PROD3 STK MILL P Time milling 2 ff/hr 9,286.7 9,287.7 19:03 19:45 5/17/2019 5/17/2019 0.50 PRODS 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 PRODS STK MILL P Time milling 10 fUhr 9,289.0 9,293.0 20:15 20:51 1 I I I 5/172019 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, dean PU's trouble getting back to bottom. Page 19/34 Report Printed: 7/1/2019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depm Start Time End Time our lhn Phase Op Code Activity Coda Time P-T-X Operation (AKB) End Depm(flKB) 5/17/2019 5/17/2019 0.20 PRODS STK WPRT T PUH, PUW 33 k, PUH min rale, 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 clean, bring pump up to 1.8 bpm, continue back to bottom, seeing weight spikes @ 9,290'-9,298' 5/17/2019 5/18/2019 2.55 PROD3 STK DRLG T BOBO, 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 5/18/2019 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 5/18/2019 4.00 PRODS STK DRLG T BOBO, 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 5/18/2019 5/18/2019 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 dean up hole for second billet set. 5/18/2019 5/18/2019 0.40 PRODS STK TRIP T RBIH to billet, dry drift, SID Q 9288.3' 8,833.0 9,288.0 07:12 07:36 4 k lbs, 5/18/2019 5/18/2019 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' 5/18/2019 5/18/2019 1.40 PRODS STK PULD T PUD BHA 20, 1-1 drilling assembly, 64.0 0.0 09:24 10:48 blow down and flush motor. 5/18/2019 5/18/2019 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 5/18/2019 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 fUmin with anchored billet 82.9 8,770.0 13:12 15:12 and 10.07' perforated pup ober a solid bullnose (LOA 21.89') 5/18/2019 5/18/2019 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 5/18/2019 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 - clean, continue in hole to 9253' PU Wt 35 k lbs. RIH to 5/18/2019 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 Ibs, CT 1031 psi, WH 557 psi Stage CT up to 2300 psi, Came online with the pump, observe shear 4,200 psi, WOB 0.77, Slack off, slack 3 k Ibs on billet - good PU 33 k lbs. 5/18/2019 5/18/2019 2.30 PRODS STK TRIP T POOH 9,291.7 72.0 15:48 18:06 1 I 5/18/2019 5/18/2019 0.20 PRODS STK PULD T At surface, space out, unstab INJH 72.0 72.2 18:06 18:18 1 5/18/2019 5/18/2019 1.50 PRODS STK PULD T PUD setting tools 72.2 0.0 18:18 19:48 1 Page 20134 ReportPrinted: 7/1/2019 operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (Wit) 5/1812019 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, makeup/torque flow sub 5/18/2019 5/18/2019 2.00 PRODS STK PULD T PD kickoff/Drilling BHA #22 0.0 78.3 20:33 22:33 5/18/2019 5/19/2019 1.46 PROD3 STK TRIP T Tag up, reset counters, RIH, testing 78.3 7,592.0 22:33 00:00 agitator @ 522', obtain snap shots 5/19/2019 5/19/2019 0.15 PROD3 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 5/19/2019 5/19/2019 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 PROD3 STK MILL T 1 Whir, 2 ft/hr, 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 5/19/2019 0.35 PROD3 STK MILL T 10 ft/hr, 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, OA=171 5/19/2019 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 His. - pump 5x5 in anticipation of build TD ROP - 164 ff/hr 5/192019 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, S/D, work pipe, PUH. Same trouble spot as seen on previous L2 lateral. Page 21/34 Report Printed: 71112019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Da) Start Depth Start Time End Time Dur hr) Phase Op Code Activity Catle Time P-T- X Operefion (n End Depth (t1KB) 5/19/2019 5/19/2019 1.70 PROD3 DRILL TRIP P Park, Open EDC, Poch 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 511912019 0.70 PROD3 DRILL PULD P PUD BHA# 22, high bend build 72.0 72.0 13:46 14:28 assembly. 5/19/2019 5119/2019 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 Chicago clamp to wire w/ sash cord lanyard run to rig floor. 5/19/2019 5/19/2019 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 S/L 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 w/test cable (good-test), slide Card forward, MU to tools, perform surface test (good-test) 5119/2019 5/19/2019 1.75 PROD3 DRILL TRIP T Tag up, reset counters, RIH 72.0 8,740.0 19:22 21:07 Mote: Tag and SID 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 5119/2019 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 511912019 5/19/2019 0.60 PROD3 DRILL TRIP T Continue displacing well to 11.68 ppg, 8,795.0 5,997.4 22:25 2301 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 5120/2019 0.30 PROD3 DRILL TRIP T Continue flow check (no-flow) 5,997.4 5,997.4 00:00 00:18 5/20/2019 5120/2019 1.00 PROD3 DRILL TRIP T POOH 5,997.4 78.3 00:18 01:18 5/20/2019 5120/2019 0.50 PROD3 DRILL OWFF T At surface, perform flow check, PJSM 78.3 78.3 01:18 01:48 512012019 5/2012019 0.50 PROD3 DRILL PULD T LD build assembly on a dead well. 78.3 0.0 01:48 02:18 5/20/2019 5/2012019 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 5/20/2019 5120/2019 1.70 PROD3 DRILL TRIP P Tag up, reset counters, RIH, surface 80.2 8,740.0 03:15 04:57 lest stryder @ 502' 5/20/2019 5/20/2019 0.20 PROD3 DRILL DLOG P Log the Kt marker for depth control - 8,740.0 8,788.0 04:57 05:09 8.5' correction. Page 22134 Report Printed: 71112019 Operations Summary (with Timelog Depths) ff 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Siert Time End Time our (hr) PI erase Op Cade AcOvlry Cade Time P -T -x Operation 0") EM Depth (MB) 5120/2019 5/20/2019 0.90 PRODS 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 PROD3 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 Ids and 2.5 k WOB. 9596'- PU 32 k lbs 9614'- PU 34k lbs 9680'- PU 35k lbs ROP = 41 fUhr 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 5120/2019 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 PRODS DRILL WPRT P PU W135 k lbs, wiper trip #1 9,950.0 9,300.0 20:00 20:12 -WOB tug @ 5/20/2019 5/20/2019 0.20 PRODS DRILL WPRT P RBH 9,300.0 9,950.0 20:12 20:24 5/20/2019 5/20/2019 1.80 PROD3 DRILL DRLG P CT 4310 psi @ 1.67 bpm in and 1.86 9,950.0 10,030.0 20:24 22:12 bpm out, free spin 724 psi, BHP 3762 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 PRODS DRILL DLOG P Tie into the Kl for + 2' correction 8,740.0 8,780.0 22:54 23:06 5/20/2019 5/20/2019 0.50 PRODS 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 PRODS 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 Wt 7.7 k lbs, WOB 1.1 k lbs 5/21/2019 5/21/2019 2.00 PRODS 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 PRODS 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 23/34 Report Printed: 7/1/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tie End Tie our (hr) Phase Op Cade Activity Code Tire P -T-% Operation (11KB) End Depth (WO) 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 PLI @ 10,263', PUW 33 k PU @ 10.292', PUW 33 k 5/21/2019 5/21/2019 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 5121/2019 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 5/2112019 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 5/21/2019 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 PROM 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 PROD3 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 5121/2019 5121/2019 2.00 PRODS 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 5/21/2019 2.80 PRODS 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' wipertdpl-ow ROP, Low 10,813.0 10,813.0 18:36 19:36 DHWOB, PUW=35K 5/21/2019 5/2112019 2.30 PROD3 DRILL DRLG P 10813', Drill, 1.9 BPM 4661 PSI FS, 10,813.0 10,904.0 19:36 21:54 IBHP=3815 5/21/2019 5/2212019 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 512212019 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 5/2212019 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 enroule 5/22/2019 5/22/2019 0.40 PROD3 DRILL DRLG P 11076', Drill, 1.9 BPM (03 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 PROD3 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 5/2212019 0.90 PROD3 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 5122/2019 0.70 PRODS DRILL WPRT P Wiper to the window, PUW 33k. 11,219.0 8,830.0 09:48 10:30 5122/2019 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 5/2212019 5/22/2019 0.90 PRODS DRILL WPRT P Wiper back in hole. RIW 13k. 8,668.0 11,219.0 10:42 11:36 Page 24134 Report Printed: 71112019 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Steil Tim End Thee Dur (hr) phase Op Code Activity Code Tana P-T-x operation (WB) End Depth dd(B) 5/22/2019 5/2212019 7.00 PRODS 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 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'wiper trip, PUW=34K 11,580.0 11,578.0 01:48 02:36 5/23/2019 5123/2019 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 5/2312019 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 512312019 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 PROM 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 523/2019 3.25 PRODS DRILL WPRT T Wiper to the window @reduced 8,644.0 80.3 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 5/23/2019 5/23/2019 0.50 PRODS DRILL PULD T Inspect BHA assembly, BHI motor 0.0 0.0 13:30 1400 lower bearing housing out of spec. 5/23/2019 5/23/2019 1.50 PROD3 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 5/23/2019 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=31 K, Swap pump 5/2312019 5/23/2019 0.30 PRODS DRILL TRIP T Continue in well, Clean pass through 8,765.0 9,460.0 17:24 17:42 window, Stack out @ 9460 5/23/2019 5/23/2019 0.50 PRODS 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 5/232019 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 25/34 ReportPrinted: 7/1/2019 -, Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth siert rime End Time our (hr) Phase Op Code Activity Code Time P -T -x Operation (f KB) End Depth (OKB) 5/23/2019 5/23/2019 0.70 PROD3 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 clean 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 5/23/2019 2.80 PRODS 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 5/23/2019 5/23/2019 0.30 PRODS DRILL WPRT P Pull BHA wiper, PUW=36K, Had to 11,988.0 11,987.0 23:30 23:48 work to get back to bottom. 5/23/2019 5/24/2019 0.20 PRODS 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 nozzle from working to bottom 5/24/2019 5/24/2019 2.20 PROD3 DRILL DRLG P 11998', Drill, 1.88 BPM @ 5080 PSI 11,998.0 12,100.0 00:00 02:12 FS, BHP=3915 5/24/2019 5/24/2019 4.50 PROD3 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 5/24/2019 0.40 PRODS 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 5/24/2019 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 PRODS 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 WHP 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 PRODS DRILL WPRT T RIH, working back to bottom with 8,875.0 10,265.0 11:12 1212 multiple set downs, 5/24/2019 5/24/2019 0.50 PRODS DRILL WPRT T 10,265' Pull wiper up hole to 9,600', 10,265.0 9,600.0 12:12 1242 PUW 39 k 5/24/2019 5/24/2019 3.25 PROD3 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 5/24/2019 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. 5/24/2019 5/24/2019 2.00 PRODS DRILL WPRT T Pull free at 41 K up. RBIH to 8940' 9,000.0 8,940.0 20:15 22:15 Stack 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: 7/112019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Stan Time End Time DW (hr) Phase Dp code Activity Code Time P -T -x operant (flkB) End Depth (WB) 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 Turn around, PUW=31K, 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 PROD3 DRILL WPRT T Park @ 49K. Pump 7 BBIs LVF. .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 -2K to 70K. 5/25/2019 5/25/2019 0.70 PROD3 DRILL WPRT T Pump 2 more BBIs. Let soak, work 8,868.0 8,868.0 03:42 0424 pipe, -10K to 70K 5/25/2019 5/25/2019 0.30 PROD3 DRILL WPRT T Pump two mare BBIs 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 PROD3 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 PROD3 DRILL WPRT T Shutdown and relax pipe and circulate 8,868.0 8,868.0 04:54 0554 0.6 bpm in tention 50 k 5/25/2019 5/25/2019 1.50 PROD3 DRILL WPRT T Circulate down the coil, squat down 8,868.0 8,868.0 05:54 0724 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 bible of LVF, 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 PROD3 DRILL WPRT T Work pipe up and down -15 k-78 k, 8,868.0 8,868.0 09:12 10:12 wtih no movement 5/25/2019 5/25/2019 4.00 PROD3 DRILL WPRT T Call for 80 bbls 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 antl RU 8,868.0 8,868.0 14:12 14:42 1 1 1 to customer line, PT 4000 psi 5/25/2019 5/25/2019 2.00 PROD3 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, let 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 PRODS DRILL WPRT T Line up down the backside, 1,400 psi 8,868.0 8,868.0 1642 1742 on the WHP, dump pressure quickly, work pipe Who 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 PROD3 DRILL WPRT T Pump pipe in compression, -10K Let 8,868.0 8,868.0 17:42 18:18 relax 5/25/2019 5/25/2019 1.30 PROD3 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 PROD3 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 Report Printed: 7/1/2019 AMR %. h,Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dw (hr) Phase Op Code Activity Code Time P -T -X operation Start Depth (aKB) EW DepM (PKB) 5/25/2019 5/25/2019 2.10 FROM DRILL WPRT T Work pipe, 75K to -15K. Pump 20 8,668.0 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 PRODS 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 PRODS DRILL WPRT T Work pipe up. alternating pumping 8,868.0 8,868.0 23:12 23:18 down backside and dumping WHP, 85K to -18K 5/25/2019 5/26/2019 0.70 PRODS 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 5/26/2019 5/26/2019 0.30 PRODS 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 PRODS 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 PRODS 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 comand. See EDC go to 200%. Pull up to 60K. RBIH. PUH again. Go to 10K Kick on pump. Loose comms with tool. Cycle CT pumping 1.8 BPM down CT SID 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 PRODS 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 PRODS DRILL CTOP T Crew change, Valve check list, walk 8,868.0 8,868.0 18:00 18:30 around 5126/2019 0.60 FROM DRILL CTOP T PJSM, Go over 2E-17 Stuck coil 8,868.0 8,868.0 15/2612019 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 PROD3 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 PRODS 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 lubed up 12.2 down coil 5/26/2019 5/26/2019 1.30 PRODS 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 5/26/2019 0.10 PRODS DRILL DISP T Pump on backside to fill hole. 1 BBI to 8,868.0 8,868.0 23:42 23:48 fill. Static loss rate 2 BBVHR Page 28134 Report Printed: 71112079 Operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phase Op Cotle ActivityCode Time P -T -X Operation alert Depth rt (WB) EM Depth (flKB) 5/26/2019 5127/2019 0.20 PROD3 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 5/2712019 5/27/2019 1.00 PRODS 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 5/27/2019 5/27/2019 1.80 PROD3 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. Cul coil 86" up from floor. Able to pull T of slack by hand. Install cable clamp on top of CT Cul E -line. Skid back injector 5/27/2019 5/27/2019 0.20 PRODS DRILL CTOP T PJSM. RON weight indicator rigged 8,868.0 8,868.0 02:48 0300 up. R/U T bar to tugger 5/27/2019 5/27/2019 0.80 PROD3 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 PROD3 DRILL CTOP T Scaffold erected. SLB e -line 8,868.0 8,868.0 03:48 04:42 equipment on rig floor. PJSM to pull a- line loose from UQC anchor with T bar. On 4th pull see anchor release @ 136010 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 0657 from CT 5/27/2019 5/27/2019 0.30 PRODS 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 bbls) 5/27/2019 5/27/2019 0.80 PROD3 DRILL CTOP T PJSM, Install BOT external graple 8,868.0 8,868.0 07:15 0803 connector, pull test to 25 k 5/27/2019 5/27/2019 0.80 PROD3 DRILL CTOP T MU, 1502 iron to stumb end of coil 8,868.0 8,868.0 08:03 08:51 with lateral and 1-1/2" high pressure hose. 5/27/2019 5/27/2019 0.20 PRODS DRILL CTOP T PT BOT CTC 800 psi good test 8,868.0 8,868.0 08:51 0903 5/27/2019 5/27/2019 1.00 PROD3 DRILL CTOP T Install addlional plug valve on 8,868.0 8,868.0 09:03 1003 manifold to PT E -line Lubricator. 52712019 5/27/2019 2.50 PROD3 DRILL ELNE T PJSM, spot, load and RU SLB E -line 8,868.0 8,868.0 10:03 1233 5/272019 5/27/2019 1.75 PRODS 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 5/272019 5/27/2019 0.70 PRODS DRILL ELNE T SLB changeout and orientation new to 8,868.0 8,868.0 14:18 15:00 the rig x 2 5/27/2019 5/27/2019 4.30 PRODS DRILL ELNE T RIH 8,868.0 8,868.0 15:00 19:18 5/27/2019 5/27/2019 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 PRODS 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 PRODS 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 PROD3 DRILL ELNE T POOH 8,868.0 8,868.0 23:27 00:00 5/28/2019 528/2019 1.20 PRODS DRILL ELNE T Continue out of well after firing chem 8,868.0 8,868.0 00:00 01:12 cutter Page 29/34 Report Printed: 7H/2079 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I Shan Depth Stan Time End Tree our (hr) Phase Op Coda Activity Code Time P -T -X Operation (We) EM Depth take) 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 5/282019 0.60 PRODS 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 5/282019 1.60 PRODS 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 5/282019 3.00 PRODS 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 528/2019 5/28/2019 0.30 PRODS DRILL CTOP T PJSM, Strip on well. Pull test splice to 8,668.0 8,868.0 09:36 09:54 30K. Open 2" pipe slip rams. Pull splice to storage reel 5/2812019 5/28/2019 2.00 PRODS DRILL TRIP T POOH with 8802' CT 8,868.0 400.0 09:54 11:54 5/282019 5/28/2019 1.00 PRODS DRILL OWFF T 400'. Flow checkwell. Unslab injector. 400.0 0.0 11:54 1254 Pull to surface. Close swab. Stab back on well 5/282019 5/282019 0.60 PRODS DRILL CIRC T Circulate CT to water recovering 12.2 0.0 0.0 12:54 13:30 Naar. PJSM w HES N2 pumpers. Start cooling down N2 5128/2019 5/28/2019 0.80 PRODS 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 PROD3 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 5128/2019 528/2019 1.00 PRODS DRILL CTOP T Prep reel for pick & removal, rig 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 rig at 19:00 hrs, 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 rig (reel # 53723) 5/28/2019 529/2019 2.00 PROD3 DRILL CTOP T Shim hubs, install saddle damps, 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 rap 5/29/2019 5/29/2019 2.10 PRODS DRILL CTOP T Continue reel install & greasing for 0.0 0.0 00:00 0206 ROPE test, change out riser o -rings from QTS to top off bag, change out brass, re -install stripper, slide back injector, fluid pack, perfrom shell test 529/2019 5/29/2019 0.80 PRODS DRILL PRTS T PJSM, line up valves per modified 0.0 0.0 02:06 02:54 checklist, perfrom shell test Page 30/34 Report Printed: 7/1/2019 operations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Start Time Erd Time our (hr) Phase Op Corte Activity Code Time P -T -X Operation (MB) End DOM (ftKB) 5/29/2019 5/29/2019 3.10 PRODS DRILL BOPE T BOPE test (250 psi low / 3800 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 charlie 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 PRODS 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 FROM 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 FROM 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 PROD3 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 FROM 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 top 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 FROM 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 FROM DRILL PRTS T Line up to test inner reel valve - iron, 0.0 0.0 09:42 10:30 1 1 and packoffs with chart to 4400 PSI 5/30/2019 5/30/2019 1.60 PRODS DRILL PULD T Unstab injector, Install floats in UQC. 0.0 71.8 10:30 12:06 PIU BHA#25. Fishing BHA with overshot, jars, weight bar, and accelorator. M/U to CT and surface test Page 31134 Report Printed: 711/2019 operations Summary (with Timelog L,epths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End T ne Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (V8) 5/30/2019 5/30/2019 1.70 PRODS DRILL TRIP T Trip in hole 71.8 8,565.0 12:06 13:48 5/30/2019 5/30/2019 0.30 PRODS DRILL DLOG T Log be in for +144' - New CT string 8,565.0 8,773.0 13:48 14:06 with protective coaling. Reel counter right on 5/30/2019 5/30/2019 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 5/3012019 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 5130/2019 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 5/3012019 0.30 PROD3 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 HS, 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 1 O 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 PRODS 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 02:18 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 5/31/2019 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 PROD3 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. 5131/2019 5/31/2019 1.50 PRODS DRILL TRIP T Pump off fish. POOH for coil fatigue 8,796.0 85.0 08:06 09:36 1 1 1 1 1 1 management 5/31/2019 5/31/2019 0.40 PRODS DRILL PULD T At surface. Flow check well. PJSM lay 85.0 0.0 09:36 10:00 I down BHA on dead well Page 32134 Report Printed: 7/1/2019 - Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Sten Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X O peratlon (rt End Depth (eKa) 5/31/2019 5/31/2019 5.00 PRODS DRILL CTOP T Prep for slack mgmt. Pull UQC Boot e- 0.0 o.o 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, P/U BHA#28 with GS, 2 1/4" 0.0 68.2 15:00 15:36 Up Down jars, weight bar, and acceloralor. Make up to cil and surtace 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 = 31K, pill built & 8,740.0 8,796.0 18:00 19:00 ready to pump, pump 35 bbl beaded/lubed pill, continue RIH, latch into fish 5/31/2019 5/31/2019 1.00 PROD3 DRILL FISH T Begin jarring down, 30 licks down, so 8,796.0 8,796.0 19:00 20:00 1 1 movement on fish 5/31/2019 5/31/2019 0.20 PRODS 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, Bow -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 6/112019 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 wl 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 07:12 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 Unslab injector, remove nozzle, Pull 0.0 0.0 09:24 09:42 Floats from UQC 6/1/2019 6/112019 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: 7/1/2019 Uperations Summary (with Timelog Depths) 2E-17 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our inn Phase Op Code Activiy CWe Time P -T -X Operation (flKB) End DepN (%KB) 6/1/2019 6/1/2019 0.80 DEMOB WHDBOP NUND P Complete unloading pits. Lid stack off 0.0 0.0 13:12 1400 well with new upper swab. RIG RELEASE 14:00 Page 34/34 ReportPrinted: 7/1/2019 I ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E -17L2 50-029-22419-61 Baker Hughes INTEQ Definitive Survey Report 26 June, 2019 BA ER t UGHES nEcomoa�y ConocoPhiliips ' W"� ConocoPhillips Definitive Survey Report Cempme, Comoolahillipr Alaska Inc_ Kupamk Protect: Kupamk River Unit Site: Kupamk 2E Pad Well: 2E-17 Waltham: ZE-172 0esli 2E-171-2 Protect Kupamk River Unit, Noah Slope Alaska, United Slates Map System: US Stale Plane 1927 (Exact solution) System Datu Geo Ommill NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 2E-17 Local Do-ordmate Reference: Wall 2E-17 No Reference: 2E-17 148.00use (2E-17) NO Reference: 2E-17 ®146.00usf1(2E-17) Noah Reference: True Survey Calculation Method: Minimum CurveWre Database: EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Position ae01 0.00 ush Northing: 5944284.83 usfl 57,405 .0m 0.00 usfl Earring: 529,971.26usb Position Uncertainty, 9 00 usfl Wellhead Elevation: usfl Wellbore 2E -17L2 Surwy Moan Date End Dafe Mag^erlcs Model Name SampN Data Declination (1) BGGM2018 7112019 1649 Design 2E -17L2 Audit Notes: Version'. 10 Phu. ACTUAL Te On Depth: 11.25219 Vertical Section: Depth From (TVD) +NIS +Et (usR) (ush) (.to 146.00 0 00 0.00 Surrsy Program Dau From To lure) (-am Survey(Welibi Tad Name Description j 150.00 8,80620 2E.17 (2E.17) GCT -MS SCMumbaryer GOT mu0ishol 8,807.00 803.11 2E-17UPBt MYAOINC (2E4712PB1) MWO-INC ONLY MIND-ING ONLY FILLER 8,893.44 11,252.19 2E-17UPSI all(2E-17t2PB1) Ill OWSG OWSG MIND - Standard 11,28100 12,906.29 2E-171-2 MWD(2E-172) MWD OWSG OWSG MWD - Standard Laftude: Longitude: Ground Lever: 70° 15' 31.049 N 149° 45' 27.910 W 0.00 usit DIp An9k FMdSDonMlh� r) Inn 80.81 57,405 __ 51162019 Directors I°) 14000 Murray Surwy Moan Date End Dafe VIV201 519/2019 51912019 51112019 511112019 5/1612019 51162019 6R62o19 230: 16PM Paget w4ala 55000.14 Build 65O Co nocoPhillips ConoeoPhillips Definitive Survey Report company: CDnoc0Phillps Alaska Inc_Kupamk Local Coror6inate Resonance: Wan 2E-17 i Project: Kupamk River Unit WO Reference: 2E-17®146.0Ousn(3E-12) SIN: Kupamk 2E Pad MD Reference: 2E-17 C 145.00usn(2E-12) NNN: 2EA7 North Reference: True immes : 2E -12L2 Survey Calculation Method: Minimum Connote. Designs 2E-1712 Database: EDT 14 Alaska Production Somi 6(WO19 2:30: 16PM pal 3 '� 9 Map Map Vertical MD Inc A! TW mw ♦}pd .0471 DLS Nombro9 Easting Section survey idol xam. Annotation ttatq PI 1°I Ilan) luau) team (.an) in) (na) (°1100•) In) 11 M.19 8514 140.63 6,094.01 5.948.01 8,746.98 4.58863 5,93],556.53 534586.25 6.12 8,118.00 MWD MSG (3) TIP 11,281.97 0537 140.05 6,0%44 5.950.14 8,769.10 4606.97 5.931 534,604.67 471 0.14623 MWID MSG (4) KOP 11,310.32 91.44 141.81 609620 Sell 8,291.05 4.544 54937,51211 534,623.0 18.29 8,126.03 MWD MSG (4) 11,30.5.99 9423 IM.52 8094.83 5,948.83 -a 819.96 4,64521 5$02.484.97 534.643.62 1665 8.210.60 MWD MSG (4) 11,32533 91% 142.92 809344 5,90.15 3,845.39 4,02. D2 5.07,40,73 5%.YA.W 11ID 8,240.59 MWD MSG (4) 114004.83 9032 145.24 6,092M 5,948.62 84820.14 4828.10 5.937,434.04 534.62620 2.10 8,5985 MWD MSG (4) 11,434.02 00.86 143.82 609200 5946.80 669422 4695.30 5,9371W.48 534.690.49 9.04 0.29920 MWD MSG (4) 11,46554 80$ 141.29 6093.46 5.7. 691813 421392 5,932,3115.5 534.21221 W 0.330.41 Metal) 0 MISS (4) 11,494.99 8297 138.9 6.094.45 5WA5 8.941.59 4.232.94 5937,362.02 571.231.32 nor 8,359.84 MWDOINGG(4) 11,52982 88.13 135.21 6,095.25 5,949]5 69,.98 4,255.88 5,932,332.62 534,255.35 060 8,39068 MrVO0WSG(4) 11.55082 88.28 133.16 609511 5,950.21 8,98228 4nB.43 5,932,31602 534.222.99 16.45 8,425.11 MPo➢MSG (4) 11,580.92 8089 15.93 6,09.67 5,95182 -7097.65 4,803.15 5932,298.01 534.801.28 1097 8454.83 MWD OWSG(4) 11,620.66 80.40 125.5 11,09802 5952.02 -2,024.15 4,822.15 5,937 MS W 531.82584 9.22 8.453.64 M OC'Na (4) 11.650.71 50.9 123.52 6,090.39 595239 4,041.13 4151.94 5,91 534.850.69 856 8.51259 MNDOWSG(I) 11,681.11 89.36 123.23 SOWN 5,952.99 -2,052.99 4.822.23 5,937 247,01 Wasn"5 3.28 8,54115 MMVDM G(4) 11.21059 90.80 15.32 6,098.90 5,95298 -2.024.20 4,90151 5937230.39 534.90040 2.14 8,520.12 MNOOWSG(4) 11,24063 111 12145 6,099.97 5,997.97 4,091.50 4,926.14 5932,21329 530,92508 5.63 8,599.9 MND 69756 (4) 11.n0n 111 12441 6099.01 5,953.01 -7108.82 4997.96 5,932,196.32 534,950W 5.30 8,111 MAD O Must (4) 41.97029 8511 10.97 6,10121 595521 -7,12552 4925.90 5,932.129.82 534924.98 9.50 3 S MND GW6G(4) 11 8424 12265 6,104.36 5,997.5 2,141.82 5,000.95 593716182 535.000.10 142 8,60551 MAD 09750 (4) 11.,065 85.58 122.5 6.197.88 5960.86 445185 505.04 5932,14214 sn'tri 3.32 6,213.91 hi 09756(4) 11.8911 0536 IMAI 5.109.25 5,96325 -2,12380 505132 5932,131.90 535.050.63 0.95 6242.40 MAD MSG (4) 11,b1069 87,5 121.61 8111.15 6,9E5.15 -2,10961 5,026.81 5.932.116.19 535,02614 6.96 8,"0.02 MAD OWSG(4) 140059 88.61 121A2 5111.91 59,.91 4,205.5 510238 5,832.100.65 536,10162 771 8299.22 MAD MSG (4) H'losi 93.10 121.86 6,111.19 5,96519 4,25.92 5.122.20 5932005.09 535,122.14 11.49 0,82152 MND MSG (4) 12.01058 93.99 12200 6108.59 5.99759 -7.236.04 5,153"2 5932,0,.22 535,15222 0.T 8,856.16 MND MSG (4) 12,04060 93.90 121.30 6,100.55 6.95255 -2,252.60 5.9871 5,932053.61 535,128.31 TO 6804.65 MND MSG (4) 12,070.0 91.97 121.24 6,10,01 5,3e201 -0.26!.35 5201.32 5.91 535303.99 1.23 0.913.10 MWD MSG (4) 12,100.88 81.20 121.28 6,102.41 5,961.42 4,284.24 5,23004 5,91 535."99.73 O.45 0,941.86 MWD MSG (4) 12,13024 9009 12151 8,107.0 Stil 0 -0,299.50 525546 5,89,0f5.6I 535255.5 3.83 8,970.19 MWD OWSG t4) 6(WO19 2:30: 16PM pal 3 '� 9 ConoeoPhiilips VIES O ConocoPhillips Definitive Survey Report Company: ComocoPhllllps Alaska Inc_Kupamk Project: Kuparvk River Una Sde: Kupsuk 2E Pad Well: 2E-17 Wellbore: 2E-111,2 Design: 2E-171,2 Survey Local Coordinate Reference: ND Resonance: Mn Reference'. North Reference: Survey Calculation Method; Database: Ub112E-17 2E-17 @ 146.00usn (2E47) 2E-17®146.00usn(2E-17) Due Minimum Curvature EDT 14 Alaska Production Annotab0n 6262019 2: 30: 16PM Putts COMPASS WOO, 14 EasO 850 Map Map Vertical MO Inc Aai TVD TVDS3 ♦WS +EI -W No Eaetin9 CLS Section Survey Tool Name (usnl ('1 1) lusnl lusnl (usn) (usn) (ft) ns Ins 1.1100'1 ns 12,160.78 8932 121.20 6.1 0].23 5951.23 -7,31553 5.281.11 5.936,991.09 535260.92 276 6,99865 MWD OWSG (0) 12192.01 0]2] 119.82 6,108 IS 5,96246 -7,331.41 5.307.99 5.936 97A33 535.307.65 ]]4 9.020.09 MO9MSG (4) 12.220.44 67.79 11985 51PJ.39 5,96339 -7,345.50 5,33260 5.93,961,25 51'x,33252 183 9,054.77 WhID MSG (4) 12250,80 6850 118.24 6.11090 5.964.90 -7,360.33 5.359.09 Sax 945.51 53,35907 7.0 9.003.10 MkYD MSG (4) 12280.59 86.81 117.34 6,112.64 593.89 -7,374,19 5.385.40 5,9393265 53.3343 3.19 9.11063 MMD CW6G(4) 12,31068 8957 116.90 6.113.59 5967.59 -7,30790 5,41217 59391936 53.41225 9.29 8,138.34 MMD MSG (4) 12.340.79 8991 116.34 6.113.73 5,967.73 -7,401.39 5,439.09 5,93,905.87 5343932 2.16 8.165.97 MMD MSG (4) 12,370.13 9009 115.13 6.11173 5,967.73 -0,414.13 5,46552 5.935 893,24 535.46589 4.17 9,192]2 MHO CWSG(4) 12399.82 69te 114.15 6,113]8 5.967]9 -7426.51 5,49250 593,8609] 535A9273 3.60 9.219.55 MMO CWSG(4) 13,43833 8569 114.39 6.11503 5,.45903 -7439.04 5,620.29 5,835,83.55 53.52055 13.04 9.247.01 MAD MSG (4) 12.161.65 86.65 113.3 6.11857 5,970.57 -0,45182 5,540.83 5939855.09 5354915 906 9,25.15 MADOW6G (4) 1249079 8823 113.06 6.19.3 5.87136 -],4[3.42 5,575.55 5.93,844,4D 53657592 3.07 9,30131 MWD MSG (4) 1252029 9198 11358 6,116.79 5,9]0.]9 -]45.09 5,60263 5.93p3203 53,60103 19.54 9,327.55 MADCAmG(4) 1255065 91.44 113.30 6,115.35 5,969.35 -7,4ST.15 5.63045 5,83020.00 5363090 8.45 9,354.67 MMD OWSG(4) 13,580,37 89.14 111.05 611520 5.06930 -7.499.00 565767 5,9as stats 53565816 814 9.31,31 MWDCWSG(4) 12.610.54 9233 115.83 6.114.81 5.959.81 -7,51180 588502 5,93,796.45 5356855a 12.11 9,408.63 Naval) OWSG(4) 12,640.64 90.31 115.31 0.114.12 5.96 12 -],524]9 5,712.16 5,93,78157 535,]1275 683 9,436.03 MVM (YASG(4) 12620.45 9035 19.51 6,11387 S96]9] -7,538.05 5]30.85 5,93770.42 53573951 7.38 9,463.35 MWC G(4) 12.703.53 80.22 116.61 6,113.85 5,96785 -7,551.73 576564 5.93756.85 535 76134 299 9,49105 MD G(4) 12,]3.28 91.44 117.30 6.11142 5,967.4 -7555.. 5782.16 5,93.743.47 535.79290 471 9,518.42 MWD OWSG(4) 12.760.28 89.112 116.45 8.113.06 5,067.08 -],5]8.78 5,818.91 5,93,730.02 53581871 810 8,546.00 MWC CWSG(4) 12,790.70 WAS 11600 6.113.06 5,3709 -7,59222 5,840.20 593.71809 535,647.05 1.89 9,5]3.84 MWO OWSG(4) 128211.35 9383 11809 6,11281 5980.83 -7.605.23 SBJ2.B4 59370378 535,8]3.74 221 9600.94 MAD G(4) 12,850.21 9387 118.01 6,111.60 5,965.60 -7,610.00 5,Seat 5,93690.32 535906.3 1205 963,40 MWD CWSG(4) 12,885.17 9265 117.55 6,106.61 5.985,01 -7,63506 5,93029 5,93,674.18 535.931.30 173 9,%0]1 MWD OWSG(4) 12.906.29 89.69 117AI 6,106.16 5906.16 -7.644.111 5,949.02 5.93.664.51 535,9500] 1.03 9,680.22 MWCGWSGGl 12,935.50 6969 19.41 6,10034 5983.34 -0,658.48 5,975.0 5,93.650.94 53876.49 000 9,]0].65 PRCI CTED WTD Annotab0n 6262019 2: 30: 16PM Putts COMPASS WOO, 14 EasO 850 10-1 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2E Pad 2E-17L2PB1 50-029-22419-71 Baker Hughes INTEQ Definitive Survey Report 26 June, 2019 BA ER F�UGHES Well Position -NI -S ConocoPhillips usM1 .- ConocoPhillips Survey Report 5ltknol0 Latpude: lean) Definitive 0.00 Company: Con000Pbtilips Alaska Inc_ Kupamk Local Coordinate Reference: Wel@E-17 Project: Kupamk River Unit TVD Reference: 2E-17 Q)t 1445.00usg(2E-17) Site: Kupamk 2E Pad MD Reference: 2E-17 Q814fi00uaft(2E-17) Well: 2E-17 North Reference: True Waltham: 2E-17UPB1 Survey Calculation Method: Minimum Curvature Oesiem. 2E-17UPB1 Database: EDT 14 Alaska Production Project Kupamk River Unit. North Slope Alaska, United States Sample Date Map system: US State Plane 1927 (Exact solution) System Datum: Mean Sae Level Geo Damm: NAD 1927 (NADCON CONUS) Usitlg Well Reference Point Map Zona: Alaska Zone 04 Using geodetic scale factor Well 2E-17 Well Position -NI -S 000 usM1 Northing: 5,944.284.83ush 5ltknol0 Latpude: lean) -Fl-W 0.00 usfl Loading: 529,971.26ma GCT -MS Longitude: looaMon Uncertamry 2E-17UP81 MWD -INC (2E-17L2PB1) 000 us0 Wellhead Elevation: 2E-17UPB1 MWD(2E-17UPB1) act Ground Level: Waltham 2E -17L PB1—_--- Magnetics Model Name Sample Date Deeumlen Dip Angle M 1'1 BGGM2018 71112019 18.49 80.81 Design 2E-17L2PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,806.20 Vertical section: Depth From"o) (--M 14600 Survey Program From Peal" 150 00 8,80]00 8.893.44 •Nh9 aEf4M (-art) (use) Doo 0.00 70' 15' 31 a49 N 149° 45'27 907 W 0.00 dam Fled Strength 1.71 57,405 DMced. P) 140.00 aurvey Bae ffimDab Enti Dan TO 5ltknol0 5gnotg lean) Survey Walloon) Tea kbma Description 8100620 2E -17(2E-17) GCT -MS Schlumberger GCTmultishot 8,863.11 2E-17UP81 MWD -INC (2E-17L2PB1) MWD -INC ONLY MWoINCt.ONLY FILLER 12,479.85 2E-17UPB1 MWD(2E-17UPB1) MWD OWSG OWSG MWID- Standard 70' 15' 31 a49 N 149° 45'27 907 W 0.00 dam Fled Strength 1.71 57,405 DMced. P) 140.00 aurvey aurvey ffimDab Enti Dan 1/1212001 5ltknol0 5gnotg 5111201g 5111/2019 6162019 2'29:39PM Pape 2 COMPASS 500014 Butld SSD Cono!Shillips �ucR� W COnOCOPhIIII(35 Definitive Surrey Report Company: ConocoPhJlips Alaska Inc Kupamk Local Co�ordl.ate Reference: 030112E-17 Project: Kuparuk River Unit WD Reference 2E -17®146.01(2E-17) Site: Kupamk 2E Pad MO Reference: 2E-17®146.00ustt(3E-17) Wall 2E-07 North Reference: True Wellbere: 2E-17L2PB1 Survey Circular.. Method Minimum Curvature Deal, 2E-17L2PB1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azl WD WOSS +Wd +Ei Northing Easrin9 DL6 Section Survey Tool Name Annotation (9sttl fl CI (1 (..it) loam Rest) IN (tt) (^1186•) IS) 880620 STU 14332 ..Rk 2 5,92432 -0,659.89 3,414.62 5,939639.02 533,4049 0.47 5,764.56 PVAGING ONLY (2) TIP 8,607.60 3738 143.31 6,07135 5,825.35 -0,600.20 3,414.91 5939638.63 533,404.35 675 5.765.05 MWD-INL_ONLY(2) KOP 8,83336 4229 140.% 691.51 594551 4,67351 3425.30 5,939,¢945 633,4479 19.% 5.781a MND-INC_ONUY(2) Inhryolared Azimuth 8,96311 57.50 138.E 6.110.64 5.964.81 -0.690.02 3,440.17 5,939,606.20 53302118 6256 5,144.68 MNG-INC_ONLY(2) Interpolated AzimJM 80344 73.22 136.65 0.12312 5.9]12 4)11,11 3,450]7 598,58798 533,448.41 50.77 5,83210 MWG OWSG(3) 8930]9 0611 13266 ei.Si 5,98361 -4.7WS9 3464.80 5.9'562.32 53347461 37.63 5,060]0 MWD MSG (3) 8,950.21 WTI Inc 61W.E 5,98478 -47%.76 3,5953 5,9',542.53 533,45636 6.84 5,89785 MWD 0W6G(3) I B,E1.E 91]0 13ZM 6,130.81 5.984.81 4,778.18 3,526.82 5,9',52121 533.519.72 795 5.929]2 MWD 01450(3) ( 9031.55 9318 43253 6,429.8 5983]2 4,,797.61 3,55991 5,93950x.' 533,540.80 614 5Bri MWD 01460(3) j 9,050.57 inkn 13274 6,127.48 5,981.48 4,09,00 3,92.94 59',481.).1 533,%2.99 723 599.35 MWD OWSG(3) 9,080.30 torn 131,07 6103E 5,97830 43702 .8 3.594.85 5,939461.83 533.584.98 7.16 6016.71 MMSG 9,110.63 98% 132]3 6,11894 5,97394 4.857,90 3,617.00 5,939441.76 533.69.20 593 6,048.39 MJVD MSG (3) SJ40'm 999 13488 6,03508 5,9699 4.1IMS9 3,63840 5,939.42124 533.62B.D 743 8,9599 MJUDOW6G(3) 8,17570 9901 136.44 6,133." 5,963.45 4,803]2 3,M.% 5,3393%,71 53365294 470 6,110,33 MND MSG (3) 8.211.33 90.03 138,26 6.10414 5,9%,14 4,929.13 3,656.43 5,939370.89 5336769x 5]1 6,14953 MWG MSG (3) 9.03132 96.71 rat 16 610028 5,954.28 4,951,82 3705.66 5,9'.348.28 5336"22 10.62 6,17526 MWD MSG (3) 9,271.10 99.' lasts 6,09611 5,950.11 4975.10 3M74 5,9'.325.08 533,714.40 H.m 6,204.12 MWD MSG (3) ' 9.336.E 9922 14550 6.01.' 5,94539 4,99651 374053 5,9'301]4 533,731,20 790 0,23344 MWD 00350(3) 9327,23 95.57 14550 6.09.93 5.941.93 5,020.57 3,75530 5,939.279.74 633,74642 13a2 626002 MWD OWSG(3) 9,36951 95.01 loom em.95 5.930.05 5,047.51 3,77311 5,939,2529 533,76405 671 6,28193 MWD OWSG(3) 9,'1.21 93.23 15170 6,082.9 5.036.9 4,074.85 VW98 59'II5.60 533,780.03 12.92 6,32307 MWOOWSGS) 9.4211]7 92.30 1526 6,08124 5,93524 5,18098 3.80272 5939.19952 533.793.87 4.89 6,351,92 PANDOWSG(3) 9145186 92.18 1611 6.00901 5,934.01 5,128.65 3,816.45 5.93917111 533,007.71 111 538200 MWDOW6G(3) 9.482.61 9912 156.35 6,9939 5,933.39 S,1%,LO 3,82948 5,938p4379 533,020.0 8I% 6,411.71 MND MSG (3) 9,51202 8963 1%.E 6,99.46 5,933.46 5.16.50 3,61.30 5.939 116.17 531 163 6,44970 Sarni 9.54145 0699 t%,69 0,9980 5,933,80 5,21940 385254 5.939090.32 533844/3 2.55 6467.76 MNGOWSGS) 9,57141 B6m t%,52 6,091.% 5931 -6.23760 3,86" 5939,062.89 533,0%.13 335 6,496.46 MND MSG (3) 9,91.47 963 1%.97 6.081.73 5,93573 5,26557 3,96.33 5,939,035.25 533,069.13 193 6,525.32 MND MSG (3) 9.631.40 lo22 15747 6,06283 5,936.83 -5.29343 3,8889 5939.09.44 533,99.94 2% 6554.18 MND MSG (3) 9.80963 8630 1%.05 6NO71 5,93771 -5.320.27 3,0'.% 5938.99.65 533,0919 4,87 6,50215 MND MSG (3) 5(152019 2:29:39PM Poe 3 COMPASS 5000.14 Budd 650 s" ConocoPhillips % 0 hilli ConocoPps Definitive Survey Report Company: ConomPhillips Alaska lim Kuparuk Local Comdfnate Reference: Mil 2E.17 Pmiecb Kupamk River Unit WO Reference. 2E-17®146.00usft(2E-17) Site: Kupamk 2E Pad MO Reference: 2E-17®146.00usfl(5E-17) Well: 2E-17 Ncnh Rekrence: True Wellb.re: 2E-17L2PB1 Survey Calculation Method: Minimum Curvatura resign: 2E-17L2PB1 Database: EDT 14 Alaska Production Map Map Virtual MG (daft) Inc 1') pal 1'1 TVD (daft) 1V055 (usft) 064.1 fuse) BE74N hull) Nonhm9 Evalma OLS 010w) Sa9tlon So,, Tool Nome Ann01ati0n m) IM (ft) 86904) 9117 156.85 6.00363 593763 -5,34].62 3.911.48 583695334 6339WE0 9.66 6,610.]] MND MSG (3) 9.730.74 doA4 155.93 6.01G.44 5,93]44 5,384.66 3,92729 5,938.916.37 533.91955 306 6,64930 MWD MSG (3) 9)5129 90.49 15710 8.06337 5,93].3] 5,40.159 3,935.31 5930.697.49 533,927.65 2.80 6,678.95 SAID MSG 137 9.760.81 9D71 15].2] 6,064.64 5,937.06 4,amn 3,946.76 5,930,070.33 533.939.20 094 6,697.15 MWD MSG (3) . 9.611,16 91]2 15729 6,06241 5936.41 0,450]8 3,08.45 5,930,84336 533.951.01 3.35 6]26.11 UNVID MSG(3) 9,841"8 929 157.96 6,081.37 6,935.37 5,48654 3,989.85 5,&30,014.68 Sta.2.52 264 67`.4.70 MWD CWSG 0) 9,870.15 92,82 15&37 6p80.00 5.934.06 5.51340 3.980.81 5,939.78T866 533,97339 237 6782,W MWD MSG ) 9,93"55 Sam 159,17 6.078.34 5,932.34 5,50263 3,99196 5,930,758.69 533.984.85 3.40 6811.60 VWVD MSG (3) 9,931.33 8"E6 "68.81 6.077.00 5.931.00 5,570.50 4002.36 5,836]3(1.85 53399635 &79 6,00Al M [)0VySG(3) 9,96"a6 90.80 158.92 6.078.35 5.930.35 -5,598.70 401294 SWILM70 534,OO&W 4A3 6MAOW ,860.32 DSG(3) 9,90&95 67.79 157.32 6.076.70 5.830.70 5,625.13 402355 5.938.676.31 5511th",]] 1"% 6,895.39 MNDOWSG13) 10,021.13 6677 15589 60]1.6" 5,93"60 5.853.)1 4,035.98 5,938,64].]0 53402930 5.10 6.925.27 MND MSG (3) 1D.046.00 8910 152.65 8.646,64 5,93208 5,676.00 4,047.19 5.93"1.811.64 53404D61 11.92 6,950.23 MWD MSG (3) 10,01,26 91.07 15412 6.0]0.41 593201 S,70TU 4062.60 5,93&593,9] 53405614 6.91 6,98370 MM MSG (3) 10.11275 92.92 155.15 6,Mel 5.93691 5736.64 4,076.08 5,93656561 531,069.73 6.73 7,014.12 MWDGWSG(3) 10,14116 93.84 158,45 6,0]524 5,92924 5,761.92 4.07.70 5938.539,]9 5340a1<5 S.6)],DOfA1 MNDCVAG(3) 10,1]0.51 9237 15SM 6.073.65 592765 5.769,0 4.09]0 5,930.51268 Saad % ttb 7,649.29 MAD MSG (3) ' 10,2110.7 9151 16064 6,08.62 5926.63 5,817,52 410.0 5,930,48426 534,102.95 5255 ],09]60 MA'DGN53(3) '0,230.61 90,0 150.74 Son.n5 5.926.05 0,845.79 4.11612 5930,466.06 534,11320 4.48 7,12588 3411006456(3) 10,26123 B6.W 158.59 S.M. 5,95.92 -5.674.21 4"2983 5938,427.69 53412412 1371 ],150.5] MND MSG (3) 10,29"]3 06% 160.90 6,07469 5920.09 -5,902.76 4,14047 5,938.39910 534.134]] ]]6 7,103.22 MND 06486(3) 10,320.33 9585 159.09 6.07618 5930.]0 5929.57 4.15023 5.938.372.41 534,14464 679 7,210.0 MND MSG (3) 10.35051 85.02 157,13 6,Dffi19 5,93319 595]49 416144 5.936.364.54 534.155.96 703 7.M&62 MWD MSG (3) 10.380.n 83.% 15614 6,020 5.936.09 5,90 .14 4.173.39 5.936316.94 5311811.02 4.78 7,264.48 MAD MSG (3) 10,410.26 850 15506 60491 5938.91 5,011.87 4,10.51 5938,29026 631180.25 5.26 7,295.75 SAT) MSG (3) - 10,440.39 87.39 15345 APeds. SW..89 6,038.95 4198.57 5.93625120 634 10,41 9.34 7,324.89 MADMSG(3) 10,4]0.5] 90.0 164,36 6.087.31 5,94131 6,065.04 4211M 5,93823&20 531. 78 1227 735410 MN0GWSG(3) 1040.31 Wu 153,60 6064,99 5,940.99 E,011.211 4,22268 5,938,214.00 53421TM 332 ],3]8.18 MAD MSG (3) i 10525.82 91.29 "64.30 6,0%.51 5.940.51 6,115]0 42350 5,938,105.64 534.231.20 324 ],40].78 MND MSG (3) 10555.32 9227 153.53 6.085.59 5,938.59 6,14218 4,249.02 5,938.160.22 534244.27 4.22 7.436.40 MWD MSG [3) f0%536 9338 15445 0,04.11 593611 6,16114 426218 S938.133.31 534.257.53 480 7,485.51 MWD MSG (3) 61642019 2:29:39PM Pate < COMAa55 WOO. 14 Budd 650 �. ConocoPhillips Si b ConocoPhillips Definitive Survey Report Company: ConocoPhltlips Alaska lnc_Kupamk Local Doardmate Resonance: Wall 2E-17 P.N.': Kupamk River Unit TVD Reference: 2E-1]®14600usb(2E-1 7) Sift Kupamk 2E Pad MO Reference: 2E-17®146.00usM1(2E-17) Well: 2E-17 Nana Reference: Trus Wellborn,: 2E-l7L2PB1 Summer Iculatlon demand Minimum Curvature Dml9¢ 2E-171-2PB1 Database: EDT 14 Alaska Production Survey Map Map Vertical kW IN: A9 TVD TVD55 'Ni n-li Northing Eastln9 DLS Section Survey Tool Name Annotation (ualp M (•) (usR) (.l (u511( (usR( (R) (R( (•1100•) (X) 10,61&16 94.43 155.13 6.062.06 5936.88 E, 1. ne 4,274,65 SLOW 106.45 534.270 31 4,19 7,49428 MAL MSG (3) 10.644.93 "All 154.41 6.0l 5,933.65 -,222.09 4,287.50 5.930.6]9.65 534.283.08 2.56 7,52296 MWD MSG (31 10. 05.09 94.33 153.98 6.0]7.61 1S31.ii1 9,249.92 4,3110.5] 5,930,052.69 534.20.34 1.5] ],552.0] MWDOWSG 10.]10.45 9 AS 154.17 6,0]538 5,90. 36 9.281.70 4.315.86 5,930028.3,9 534,311.68 4.66 ].566.]1 MWD MSG (3( lo'Mw 93,14 15.49 6,073.83 S.W.63 9.300.52 4,32836 5937,994.21 534,324.16 2.68 7,614.78 RIM 60786(3( 10,]]0.]3 9305 156.50 6,071.0 5192596 -,338.58 4,340.75 5,937.95.3,1 SN MRS 401 ],544.20 IJWD CRISIS (3) 10.79546 89.17 156.04 6,071.30 592531 -,35.20 4,350.70 5,93].94].82 534.346.]9 111 7,661 MJrDMSG (3) 1662552 86.84 1886 Sidi 35 5,926.35 9,30.72 4,36215 5,93],91616 534.353,5 0.02 7,696.83 MND MSG (3) 10.81 663,5 15180 6,074.30 5.928.30 9,418.04 4377.87 5,937,004.89 51 13,93 7.730.55 MND MSG (3) 10.89070 06.40 151.49 6,0]55& Samn0 9.411.11 4,39220 593],858.28 531,388.70 5.54 705.1 MWD MSG (3) 10,920.3] 00.0 149.80 BOM.2] 5,91 1,47054 4,405.85 5,937632.52 534.403.38 664 ],78838 MWD OWBG(3) 10.950.65 86+40 10.16 60]597 5.931 -,49672 4422.03 5.937.80.40 534418.6] 2.0 7,015.21 MWV M33 (3) 10,90.43 85.78 ISO. 6,one 5,9323,3, 9,52255 4436.70 5,937,751 5343,]3.52 8.82 ],848.4] MWD GWSG(3) 11,010.51 86.93 1.,ca 608039 5.934.39 9,54652 445162 5,51 5]4440.0 an 7,878.04 MWD OWSG(3) 110410 al 140.10 6,062.12 5,83812 -,575.40 4,468.10 5,0],]Y7.91 53,,T CS 444 7,0909 MJUDGWSG(3) 11.0]2.]6 88.25 14].35 6083.45 5,937,45 1,60100 440452 5,01"I'l 534,48157 5.36 7,53855 MNDOW6G(3) 11,10189 0739 146.0] 6,084.0 5,938.56 1,62593 4500.30 5.931 534,497.53 3.37 7,00.54 MND MSG (3) 11.131.90 MAO 14597 6.005.74 5,939.74 -,65.82 4,516.91 5,937,652.69 534.514.16 3.83 7,0024 MWD Mi (3) i 11.16274 86.28 144.45 1l 5941.25 9,676.12 4,534.49 5,93762747 534.531.83 7.68 8,028.92 MWD MSG (3) 11,1a200 8568 142.80 6.0P936 5,943.% 9,65970 4.51.83 5,937,603.0 534,543,.3, 5.51 6,056.13 MWD 6073,6(3( 34,222.19 8542 14245 8,091.3,1 5,915.54 1,72157 4,570.04 5.937.51 534,5]% 209 8,098.12 MWD OWSG(3) 11,252.19 0514 14063 6,119401 5.91 6.745.0 4,50883 5.937.558.83 sm'ic .25 6.12 8,110.0 MWtGovi 3) 11281.86 8640 140.0 50019 590.19 4,769.63 4607.41 5,937.534.26 G34,61 4.70 8,14]42 MWDGW6G(3( 11,311.63 8506 13739 5098.41 5,95241 -6 MON 4,627.11 5.867,511.0 534,624.0 90 8,1]]37 MND MSG (3) 11343.87 81 137.40 6,10,80 5954.0 9,01558 4.60.73 5,07,486.40 534,64SS2 4.0 0.209.19 MJN OWSG(3) 11,37204 Sell 13537 6,102.18 59%.10 1,M Od 465830 5,937,4660 53466-.2- 851 0.23746 MNOMSG (3) 11,401.]] 09. 134.79 8.102.78 5,91 9,857.11 4,689.30 593].44].12 534.687.35 5.72 8,26].0] MND MSG (3) 11431.84 65.97 135.15 8134.91 5,957.92 -,8]638 4,71023 5,937425.93 534.70839 13.16 8.2%.82 MWD MSG (3) 11.481.87 86]8 134.93 6,105.0 5959.83 -tike 91 4,731.36 5,937,404.48 Sail 57 484 8.328.0 MWOMSG (3) 11.49311 86.5 134.70 610].0 S'skins 9,92189 4,753.49 5,937,382.5 534.]51,]8 102 0,357.0 MWD MSG (3) 11.52150 8800 135.04 610.5 5,03.50 1.941.94 4.773.62 5,937,362.0 SIR 77199 2.30 O,sa 6 MWp 6073,6(3( 6252019 229:39W Pape5 COMPASS SW0148uAd BSD ✓ ConocoPhiuips Butra,, t ConocoPhillips Definitive Survey Report Compeer. ConocoPhilhips Alaska Inc Kuparvk Local Cocrdkafe Reference: We112E-17 Protest: Kuparvk River Dnil ND Reference: 2E-9@146.00usg(2E-17) 'Mon Kuparvk 2E Pad MD Reference: 2E-17 a 146.00usg(2E-17) Ill 2E-17 North Reference: True yNgbore: 2E-17UPB1 Survey Calculation Methotl: Minimum Curvature Design: 2EA712P81 Database: EDT 14 Alaska Production Sullmy MD km AE 1134 TWSS Ng48 +6234 Map Map OL5 VenlEast].,Section Nonhing East 5uney Toolwma Annotation N-114 C) (1) tueM tu-M (ualli (--ft) (g) (g) (°110D') (tit 11.551.69 84.68 134.66 6,1179! 5,96594 4,963.10 4,]94.90 5937,341.55 530.793.35 456 8,416.14 MWO ONSG(3) 11,582.03 NA3 13501 8,11482 5.969.92 8,9843] 4,016.20 5,93],320.3] 534.014.82 243 D.M6.18 MWD 0066 (3) 11,61151 64.% 134.61 6,117.86 5.971.86 -],00506 4,837.12 5.937,299.71 5%.835]3 2Z5 8,495.43 MWD 03450 (3) 11.641]5 8]]8 134.8 6,119.08 5,873.86 -0,053] 4,858.57 5,93]2]0.65 534.85].2] 1059 8,%5.46 MND Gusto (3) j 11,63195 87.45 13460 6,121.14 5,975.14 -7,04749 4,080.02 5,937,29.51 534,07&W 1.03 6,%5.51 MND 0WSG(3) 11.702.11 07.63 135.20 SAM.40 5,06.44 -],060.]9 4,90133 5,937.236.33 534,9[020 208 &5[5.% MND OW6G(3) i 11,731.71 89.0 136.41 6.123.15 5,9]].15 -0,90.02 4.921.0 5.07,215.15 534,9211.89 7.6T 0,595.04 MND OWSG(3) 11,761.47 0&TL 137.00 6.43.33 5,97].33 -7,111.60 4.94235 5,937.193.56 534,941.38 2.02 8,624.75 MD 0WSG(3) t1.]at64 6&66 138.10 8.123.34 5.97].44 -7.133.94 4.962]2 5,937,17140 534,961,03 3.60 865489 MWDOW9G(3) 11,020.% 89.09 139.01 SIM.70 5,ST710 -],155.]1 4,981.94 5,937149.71 534901.14 4.17 0,68392 MWDOWSG(3) 11,90JI7 05.85 137.91 6.125.63 5,8]903 -7,118.28 5,001.83 5,93],12].22 535001.@ 11.30 871406 MWD MSG (3) 11,080.62 0145 136.95 6,12&32 5.90232 -7,200.05 5,021.93 5,937.105.53 53502133 15.13 0.74159 MWD MSG (3) 11,910.62 0052 13394 6,1330.1 5807.03 4,Ml.16 5.04272 5,937,004.51 535,04217 10.30 0.77313 MWD MSG (3) 11,940.50 03.0 132.40 6,137.23 5,991.23 -7,241.40 5.034.29 5,937061.36 535.363.62 10.50 8,111 MAD MSG (3) 11,970.44 0727 13015 6,139.70 5993.70 -7.4107 5,063.71 5,937044,]7 535.01 155 0,63198 KIMD OWSG(3) 12 01035 0]4 130.0 8,140.22 5.994.@ -0,28050 5,109.44 5.937.025.44 535.109.12 11.07 8,861.47 MIND OWSG(3) 1;0320 91,30 127.09 6,139.61 5,993.61 -7,301.02 5,134]7 5,937.0003 5351N.54 11.85 9893.47 MND OWBG(3) 12.050 0,6a 123.56 6139.02 5,99&02 -0,320.0 5.161.55 5,93&98815 535.161.39 10.90 0.93533 MND ONSG(3) 4,00.00 0939 U,de 6139.01 5.893.01 -7,332.99 5,182.07 5,936.893.25 535.1010 11.55 6948.36 MNO OWSG(3) 12.119.91 89.26 11901 6,139.36 5,99336 -7,34&10 5,207.]0 6,936,950.23 535,207 72 4.31 8,9]64] MND OWSG(3) 12,151.10 iS. 11386 6.139h 5.993.72 -7,363.82 5234.83 5936,94283 535X3484 0.54 9,05]5 MWD 0WSG(3) j 12,180.96 90.00 121.19 613907 5.993.07 -],3]&]9 5,20,% 5,935.07]7 535.20,61 4.85 9,033.0 MWD OW6G(3) 12.210.08 90.03 12170 Sin.80 5,993.86 -7,39399 5,205.39 5936.912.05 5352&5.51 2.03 9.051.51 MND Mats (3) 12.240.12 90.37 42es 6,139.76 SAl -741001 5,31060 5,936,695.75 S3,3ID.98 3.00 9,09011 MND OWSG(3) 1227010 89.85 12233 6,10.70 5,&4.20 -7,426.11 5,336.09 5,936.880.75 535,336.33 202 9,11&70 MWD OW60(3) 12,29961 89.20 1YBT 6.1304 5.99194 -7,44201 5.36095 5,936.864.0 535,361.25 2.86 9,14806 BIWOMSG (3) 12,330.06 9265 121.9] 6,139.45 5,99145 -7,45&30 5.31 138 5936.048.76 535.367.03 110 9,17587 MWD MSG [3) 12,359.93 96.25 120.78 6.13713 5,991.13 -0.4M78 5,41210 5936,83338 53541252 1259 3X0,00 MWD MSG (3) 4,390.04 99.82 1211.69 6,13291 598683 -7,460.02 5,43].]2 5 8 2 936035 535.43&20 119 6 23222 9MWD OWSG(3) 1?43410 102.25 119.61 6,4].17 5,901.1] -7,50304 546323 5,936.01% 535463.7 8.82 9,25997 MAD GWSG(3) 12.449n 10271 119]] 6.120]6 59]4.]6 -7,518.19 548840 5936.]0929 535480,99 1.64 9,207,14 MWD 00560(3) 526QO 19 2:29: 39PM Page 6 COMPASS WOO 14 Bui1.1 650 r, ConocoPhillips ConocoPhllhps Definitive Survey Report Company. Cono0oPhllllps Alaska Inc Kuparvk Local Cocahmate Reference: Mil 2E-17 Project: Kuparuk Rrver Unit ND RMerence: 2E-11 Qj 146.00usR(2E-17) She: Kupamk 2E Pad MO Reference: 2E-17 C 145.00ustt(2E-17) Well: 2E-17 North Reference: Tma WeIISom: 2E617UP51 Survey Calculation Method Minimum Curvature Design: 2E-17L2P51 Database. EDT 14 Alaska Production Survey —_ Map Map Vertical M11 Inc TVD NONIS jELW OLS (.111 1°1 V) 1°1 lush) ttl loan) (usnl Northing lusRl Easting Section Survey Tool Name 1°1100.1 (it) (it) IR 12479,85 102.11 12039 fi.110.30 5968.30 -]53391 5,51382 5936.]]46) 535519.96 261 9314.76 MWOOWSG 131 12.537.00 Its 1 120.39 6.10231 5.956.31 -],561.1] 5,582.02 5, 936,74fi.6n 535.582.79 0.00 9.36139 PROJECTED to TO Annotation N 0192:29'39PM Papel COMPASS 5000. 14 Sold 850 219055 BA_ ICER jePdNT DISTRIBUTION LIST 30 94 1 UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2E -17L2 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cilbakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 BP North Slope. LOA, PBOC, PRB-20 (Office 109) D&CWO Wells Admin Brenda Ghosmaker & 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 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 to acknowledge receipt of this data. LOG TYPE GR- RES LOG DATE May 16, 2019 TODAYS DATE July 1, 2019 Revision No Details: Rev. Requested by: -- FIELDI FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES I#QFCOPIES # OF COPIES 4 lu 4 is is JUL 0 2 2019 AOGCC 0 0 0 0 0 4 State of Alaska - AOCCC 0 1 1 0 0 Attn: Natural Resources Technician It 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 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. O O 0 0 0 Petrotechnical Data Center, LR24 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 b3 k CER HUGHES 01-9)PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2E-17L21PB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Riderpbakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PR&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. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 .Anchorage, AK 99503 Wn 219055 30 94 2 ;e sign and return one copy of this transmittal form to. DcoPhillips Alaska, Inc. Osterkamp (WNS Petroleum Technician) G Street. ioraae. Alaska 99510 LOG TYPE GR - RES LOG DATE May 11, 2019 TODAYS DATE July 1, 2019 Revision Details: Rev. Requested by: --- FIELD I FINALCDIDVD FINAL PRELIM LOGS (las, dlis. PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINT ur rmom # OF COPIES I#OFCQPlE5 # OF COPIES 4 4 4 4 4 1� RECEIVED OGCC 0 1 0 4 State of Alaska - AOGCC 0 1 'I 0 0 Attn: Natural Resources Technician 11 333 W. 71h Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 0 0 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 1 0 1 0 1 0 1 0 TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE ALASKA 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 -17L2 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-055 Surface Location: 642' FSL, 160' FWL, SEC. 36, TI IN, R9E, UM Bottomhole Location: 2134' FNL, 1565' FWL, SEC. 7, TION, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaslka.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 Z day of April, 2019. RECEIVLU STATE OF ALASKA ' Al_ ,,KA OIL AND GAS CONSERVATION COMMISSION APR 0 5 2019 PERMIT TO DRILL on nnc 95 005 n nn Ia. Type of Work: tb. Proposed Well Class: Exploratory - Gas ❑ `VService y WAG ❑ Service - Disp ❑ 1 c. Spe for: ❑ Gas Hydrates ❑ Drill ❑ Lateral ❑Q Stratigraphic Test ❑ Development - Oil ❑Q Service - Winj ❑ Single Zone Coalbed Gas 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-1712 3. Address: 6. Proposed Depth: 12, Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13700' TVD: 6113' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. srVer y �Dees.ignation: &5 665 Surface: 642' FSL, 160' FWL, Sec 36, T11 N, R9E, UM AOL-SSGJ ADL i%QL 2$ L 8. DNR Approval Number: �� $,Ltr1 t 13. Approximate Spud Date: Top of Productive Horizon: 1261' FSL, 1709' FEL, Sec 1, TION, R9E, UM LONS 84-029 4/18/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2134' FNL, 1565' FWL, Sec 7, T1 ON, R1 OE, UM 2560 8435' 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: 1573', 1L -23L1-02 16. Deviated wells: Kickoff depth: 8807 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 -SO ST -L 4898' 8802' 6068' 13700' 6113' Slotted /Blank 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 NIA Hydraulic Fracture planned? Yes E] No ❑Q 20. Attachments: Property Plat❑ BP Sketch B DSelin ram t Time v. Depth Iabed Shallow Hazard Analysis B✓ AAC 25 050 ements8 DivertOer Sketch ReFrog port Drilling Fluid ProgPa0 20 requi 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: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrin co .Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 ,J ! Date: '7 09,1/y Authorized Signature: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- a I q —g I — 00 1 Date: requirements. Conditions of approval If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yesr❑-��No5 Mud log mq'd: Yes ❑ No� Other:,50/-2 tC,S f fn 3 Sao h 5 q J H2S measures: Yes Ly No[] Directional svy req'd: Yes No[] %fv+r rr i—rr,!.-if2-r lz"YS ��O Spacing exception req'd: Yes ❑ No� inclination -only svY req'd: Yes E] No Lq O /n yrl Post initial injection MIT req'd: Yes ❑ NOR- -4 re2.rn Bop APPROVED BY I / 7 Approved by: COMMISSIONER THE COMMISSION Date: l �o�al � � UAL L %1 UJ 1 Submit Form and orm 10-4_000""/1IIlRevis 5/2017 This permit is valid for 2 t ro t e da a of approval per 20 AAC 25.005 gl Attachments in Duplicate LT Yq s: r.8. "4111 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-171-2 targeting the Kuparuk C -sand interval. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 2E -17L1 & 2E-171-2 — Detailed Summary of Operations — Directional Plans for 2E -17L1 & 2E -17L2 — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, eith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska 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 Summary ................... ..... ...... ..... ...... ..... ....... ..... 2 (Requirements of 20 AA C 25005(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 AA C 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)).........................................._.._................_.................._.,...................................................... 114 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)J ................ ............._..- .................... .........._..... ....... .......................4 Summaryof Operations............................................................................................................................... .......4 Liner Running 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(b))_ ... .................. .................. ...................._................_.................._................................................. 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 2E-171-1 and 2E -17L2 laterals.................................................................................6 Attachment 2: Current Well Schematic for 2E-17............................................................................................................6 Attachment 3: Proposed Well Schematic for 2E -17L1, and 2E-171-2 laterals..................................................................6 Page 1 of 6 April 04, 2019 PTD Application: 2E-171-1 & 2E -17L2 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2E-171-1 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. 1,3 O P S fu tk SG htwe 4 f� h� r� 3. Blowout Prevention Equipment Information and PS a fi a i (Requirements of 20 AAC 25.005 (c)(3)) Z/' f- v Please reference blowout prevention (BOP) schematics em file with 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 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 1 L-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 ADDlicatlon: 2E-171_1 & 2E -17L2 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New ComDletion Details Lateral Name Liner Top Liner Btm ==SS Liner Btm Liner Details Btm MD MD MD Burst psi TVDSS Conductor 16" 62.5 H-40 Welded Surface 2%", 4.7#, L-80, ST -L slotted liner; 2E-171_1 8,822' 13,300' 5,937' 5,949' deployment sleeve on to 36 J-55 BTC Surface 4,481' 2%", 4.7#1 L-80, ST -L slotted/blank 2E-171_2 8,802' 13,700' 5,922' 5,967' liner; deployment sleeve on to Existing Casing/Liner Information Category OD Weigh Grade Connection Top MD Btm MD Top TVD TVD 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 1 L-80 JEUE8RM Surface 8,862' Surface 6,115' 1 10160 1 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 -17L1 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 si Choke Pressure Required to Maintain Tar et 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 -17L1 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 Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2E -17L1 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 -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 13,700' MD. d. Run 2%" slotted/blank liner with deployment sleeve from TD up to 8,802' MD. 4. Obtain SBHP, freeze protect, NO BOPE, and RDMO Nabors CDR3-AC. Post -Ria Work 1. Return to production 2E -17L1 & 2E -17L2 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 bi deployment. A floor valve is made up onto this joint ahead of time, deployment drill with this emergency joint on every slotted liner run. secondary well control while running 2%" liner. standing by for emergency and the rig crew conducts a The 2%" rams will provide Page 5 of 6 April 04, 2019 PTD Application: 2E -17L1 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 (1R-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 -17L1 1,354' 2E -06L1 2E-171-2 1,573' 11--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-17L21aterals. Page 6 of 6 April 04, 2019 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 2E Pad 2E-17 2E-171-2 Plan: 2E-17L2_wp02 Standard Planning Report 03 April, 2019 BA UGHES a GE company ConocoPhillips 2E-17L2_wp02 ConocoPhillips Database: OAKEDMPI Company: _ConocoPhillips Export Company Project: Kupamk River Unit Site: Kupamk 2E Pad Well: 2E-17 Wellbore: 2E-171-2 Design: 2E-17L2_Wp02 ConocoPhillips 2E-17L2_wp02 Planning Report Local Co-ordinate Reference: Well 2E-17 TVD Reference: Mean Sea Level MD Reference: 2E-17 Q 146.00usft (2E-17) North Reference: True Survey Calculation Method: 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 BAT,ES a GEmmp W She Kupamk 2E Pad 2E-17L2_wp02 Site Position: Northing: 5,944,247.48 usft Latitude: 70° 15'31.481 N From: Map Easting: 529,971.75usft Longitude: 149° 45'27.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.23 ° Well 2E-17 2E-17L2_wp02 — Well Position -NIS 0.00 usft Northing: 5,944,284.83 usft Latitude: 70° 15'31.849 N +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: 0.0ausit Wellbore 2E-171-2 Magnetics Model Name Sampfe Date Declination Dip Angle Field Strength (1) (1 (nT) BGGM2018 7/1/2019 16.49 80.81 57,405 Design 2E-17L2_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,806.20 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 140.28 4/32019 12.'10:58PM Page 2 COMPASS 5000.14 Build 85D �, ConocoPhillips Bp�(ER Conoco Planning Report U3E a GErompany 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-1712 Azimuth System Design: 2E-17L2_wp02 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +W -S +El -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°HOOusft) (°I100usft) (°MOOusft) (^) 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 8,807.00 37.38 143.31 5,925.35 -4,660.28 3,414.91 0.76 0.00 -1.25 -90.00 8,832.00 41.88 143.31 5,944.60 4,673.07 3,424.44 18.00 18.00 0.00 0.00 8,943.38 92.00 143.31 5,986.85 4,752.65 3,483.73 45.00 45.00 0.00 0.00 9,100.00 91.96 132.34 5,981.42 4,868.47 3,588.66 7.00 -0.02 -7.00 270.00 9,300.00 90.22 146.23 5,977.60 -5,019.67 3,718.77 7.00 -0.87 6.95 97.00 9,550.00 91.71 163.67 5,973.36 -5,245.24 3,824.19 7.00 0.60 6.98 85.00 9,750.00 98.62 151.44 5,955.31 -5,428.92 3,899.93 7.00 3.45 -6.12 300.00 9,950.00 91.48 139.34 5,937.66 -5,592.41 4,012.90 7.00 -3.57 -6.05 240.00 10,250.00 92.28 160.34 5,927.73 -5,850.20 4,162.71 7.00 0.27 7.00 87.50 10,500.00 89.18 143.11 5,924.53 -6,069.49 4,280.68 7.00 -1.24 -6.89 260.00 10,650.00 88.65 132.62 5,927.38 -6,180.55 4,381.15 7.00 -0.36 -6.99 267.00 10,950.00 88.02 153.62 5,936.20 -6,419.07 4,560.11 7.00 -0.21 7.00 92.00 11,150.00 90.49 139.84 5,938.82 -6,585.86 4,669.55 7.00 1.23 -6.89 280.00 11,345.00 92.82 153.29 5,933.17 -6,748.13 4,776.70 7.00 1.20 6.90 80.00 11,550.00 90.51 139.12 5,927.18 -6,917.97 4,890.39 7.00 -1.13 -6.91 261.00 11,950.00 79.89 113.09 5,961.18 -7,151.05 5,208.76 7.00 -2.66 -6.51 247.00 12,150.00 89.89 122.93 5,979.01 -7,244.48 5,384.12 7.00 5.00 4.92 45.00 12,350.00 90.86 136.90 5,977.69 -7,372.50 5,537.13 7.00 0.49 6.98 86.00 12,500.00 94.93 127.21 5,970.10 -7,472.72 5,648.19 7.00 2.71 -6.46 293.00 12,600.00 89.56 122.72 5,966.18 -7,529.94 5,730.04 7.00 -5.37 4.49 220.00 12,800.00 89.57 108.72 5,967.70 -7,616.50 5,909.78 7.00 0.01 -7.00 270.00 13,100.00 90.14 129.71 5,968.46 -7,762.09 6,170.16 7.00 0.19 7.00 88.50 13,400.00 90.13 108.71 5,967.75 -7,907.66 6,430.55 7.00 0.00 -7.00 270.00 13,700.00 90.12 129.71 5,967.09 -8,053.24 6,690.95 7.00 0.00 7.00 90.00 41342019 12: f0.'SBPM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Planning Report BAF�UGHES a GE.rnpar Database: OAKEDMPI Local Coordinate Reference: Well 2E-17 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2E-17 Q 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E-171-2 Design: 2E-171-2 wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System -NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,806.20 37.38 143.32 5,924.72 4,659.89 3,414.62 5,766.34 0.00 0.00 5,939,639.02 533404.06 TIP 8,807.00 37.38 143.31 5,925.35 -4,660.28 3,414.91 5,766.83 0.76 -90.00 5,939,638.63 533,404.35 KOP 8,832.00 41.88 143.31 5,944.60 4,673.07 3,424.44 5,782.75 18.00 0.00 5,939,625.89 533,413.93 End 18 dig, Start 45 dig 8,900.00 72.48 143.31 5,981.02 -4,718.35 3,458.18 5,839.14 45.00 0.00 5,939,580.75 533,447.84 8,943.38 92.00 143.31 5,986.85 -4,752.65 3,483.73 5,881.85 45.00 0.00 5,939,546.56 533,473.53 End 45 dig, Start 7 dig 9,000.00 92.00 139.34 5,984.88 4,796.82 3,519.09 5,938.42 7.00 -90.00 5,939,502.53 533,509.06 9,100.00 91.96 132.34 5,981.42 4,868.47 3,588.66 6,037.99 7.00 -90.14 5,939,431.16 533,578.91 5 9,200.00 91.10 139.29 5,978.75 4,940.11 3,658.30 6,137.59 7.00 97.00 5,939,359.81 533,648.82 9,300.00 90.22 146.23 5,977.60 -5,019.67 3,718.77 6,237.43 7.00 97.19 5,939,280.50 533,709.60 6 9,400.00 90.82 153.21 5,976.69 -5,105.97 3,769.15 6,336.01 7.00 85.00 5,939,194.41 533,760.33 9,500.00 91.42 160.18 5,974.73 -5,197.74 3,808.68 6,431.86 7.00 85.06 5,939,102.81 533,800.22 9,550.00 91.71 163.67 5,973.36 -5,245.24 3,824.19 6,478.30 7.00 85.20 5,939,055.37 533,815.91 7 9,600.00 93.46 160.64 5,971.11 -5,292.78 3,839.49 6,524.65 7.00 -60.00 5,939,007.89 533,831.40 9,700.00 96.91 154.53 5,962.07 -5,384.79 3,877.43 6,619.67 7.00 -60.14 5,938,916.04 533,869.71 9,750.00 98.62 151.44 5,955.31 -5,426.92 3,899.93 6,667.99 7.00 -60.69 5,938,872.01 533,892.38 8 9,800.00 96.86 148.39 5,948.58 -5,471.78 3,924.77 6,716.83 7.00 -120.00 5,938,829.25 533,917.36 9,900.00 93.28 142.34 5,939.74 -5,553.68 3,981.36 6,815.98 7.00 -120.41 5,938,747.59 533,974.29 9,950.00 91.48 139.34 5,937.66 -5,592.41 4,012.90 6,865.93 7.00 -120.95 5,938,708.99 534,005.98 9 10,000.00 91.63 142.84 5,936.30 -5,631.30 4,044.29 6,915.90 7.00 87.50 5,938,670.23 534,037.52 10,100.00 91.91 149.84 5,933.22 -5,714.44 4,099.66 7,015.23 7.00 87.59 5,938,587.32 534,093.22 10,200.00 92.16 156.84 5,929.66 -5,803.69 4,144.47 7,112.52 7.00 87.81 5,938,498.25 534,138.38 10,250.00 92.28 160.34 5,927.73 -5,850.20 4,162.71 7,159.95 7.00 88.06 5,938,451.82 534,156.80 10 10,300.00 91.66 156.89 5,926.01 -5,896.72 4,180.93 7,207.38 7.00 -100.00 5,938,405.38 534,175.21 10,400.00 90.42 150.00 5,924.18 -5,986.10 4,225.60 7,304.67 7.00 -100.12 5,838,316.18 534,220.23 10,500.00 89.18 143.11 5,924.53 -6,069.49 4,280.68 7,404.01 7.00 -100.24 5,938,233.03 534,275.64 11 10,600.00 88.82 136.12 5,926.27 -6,145.60 4,345.43 7,503.92 7.00 -93.00 5,938,157.18 534,340.68 10,650.00 88.65 132.62 5,927.38 -6,180.55 4,381.15 7,553.64 7.00 -92.88 5,938,122.38 534,376.54 12 10,700.00 88.53 136.12 5,928.61 -6,215.50 4,416.88 7,603.35 7.00 92.00 5,938,087.57 534,412.40 10,800.00 88.31 143.12 5,931.38 -6,291.60 4,481.60 7,703.24 7.00 91.91 5,938,011.74 534,477.41 10,900.00 88.11 150.12 5,934.51 -6,375.01 4,536.56 7,802.52 7.00 91.72 5,937,928.55 534,532.70 10,950.00 88.02 153.62 5,936.20 -6,419.07 4,560.11 7,851.46 7.00 91.50 5,937,884.59 534,556.43 13 11,000.00 88.63 150.17 5,937.66 -6,463.15 4,583.65 7,900.41 7.00 -80.00 5,937,840.61 534,580.14 11,100.00 89.87 143.28 5,938.97 -6,546.70 4,638.47 7,999.71 7.00 -79.90 5,937,757.29 534,635.29 11,150.00 90.49 139.84 5,938.82 -6,585.86 4,669.55 8,049.69 7.00 -79.81 5,937,718.26 534,666.52 14 11,200.00 91.09 143.29 5,938.13 -6,625.01 4,700.63 8,099.66 7.00 80.00 5,937,679.23 534,697.75 11,300.00 92.29 150.19 5,935.18 -6,708.54 4,755.42 8,198.92 7.00 80.05 5,937,595.93 534,752.87 11,345.00 92.82 153.29 5,933.17 -6,748.13 4,776.70 8,242.98 7.00 80.25 5,937,556.43 534,774.31 15 4!32019 12: f0.58PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA ER F U COnOCO�'tillIpS Planning Report GHES aGEcoinpany Database: OAKEDMPI Casing Points Local Co-ordinate Reference: Well2E-17 Measured Company: _ConocoPhillips Export Company Depth TVD Reference: Diameter Mean Sea Level (usft) Name (in) Project: Kuparuk River Unit 5,967.09 2 3/8" 2.375 MD Reference: 4/3/2019 12:10:58PM 2E-17 @ 146.00usft (2E-17) Site: Kuparuk 2E Pad North Reference: True Well: 2E-17 Survey Calculation Method: Minimum Curvature Wellbore: 2E-1712 Design: 2E-17L2_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth inclination Azimuth System +N/ -S +El -W Section Rate Azimuth Northing Easting (usft) V) (_I (usft) (usft) (usft) (usft) ('1100usft) V) (usft) (usft) 11,400.00 92.21 14949 5930.76 -6796.36 4,803.01 8,296.89 7.00 -99.00 5937,508.31 534,800.80 11,500.00 91.08 142.58 5,927.88 -6879.21 4,858.83 8,396.28 7.00 -99.17 5937,425.69 534,856.94 11,550.00 90.51 139.12 5,927.18 -6,917.97 4,890.39 8,446.26 7.00 -99.37 5,937,387.06 534,888.65 16 11,600.00 89.14 135.90 5,927.33 -6,954.84 4,924.15 8,496.20 7.00 -113.00 5,937,350.33 534,922.56 11,700.00 86.42 129.45 5,931.20 -7,022.53 4,997.57 8,595.18 7.00 -112.99 5,937,282.94 534,996.24 11,800.00 83.74 122.95 5,939.78 -7,081.35 5,077.91 8,691.76 7.00 -112.74 5,937,224.45 535,076.81 11,900.00 81.15 116.40 5,952.94 -7,130.41 5,163.98 8,784.50 7.00 -112.18 5,937,175.73 535,163.06 11,950.00 79.89 113.09 5,961.18 -7,151.05 5,208.76 8,828.99 7.00 -111.32 5,937,155.28 535,207.92 17 12,000.00 82.37 115.58 5,968.88 -7,171.40 5,253.77 8,873.41 7.00 45.00 5,937,135.10 535,253.00 12,100.00 87.38 120.50 5,977.82 -7,218.21 5,341.61 8,965.55 7.00 44.62 5,937,088.65 535,341.02 12,150.00 89.89 122.93 5,979.01 -7,244.48 5,384.12 9,012.93 7.00 44.18 5,937,062.55 535,383.64 18 12,200.00 90.13 126.43 5,979.00 -7,272.93 5,425.24 9,061.08 7.00 86.00 5,937,034.27 535,424.86 12,300.00 90.62 133.41 5,978.34 -7,337.05 5,501.88 9,159.39 7.00 86.00 5,936,970.45 535,501.75 12,350.00 90.86 136.90 5,977.69 -7,372.50 5,537.13 9,209.17 7.00 86.05 5,936,935.16 535,537.14 19 12,400.00 92.23 133.68 5,976.34 -7,408.01 5,572.29 9,258.96 7.00 -67.00 5,936,899.78 535,572.43 12,500.00 94.93 127.21 5,970.10 -7,472.72 5,648.19 9,357.23 7.00 -67.09 5,936,835.38 535,648.59 20 12,600.00 89.56 122.72 5,966.18 -7,529.94 5,730.04 9,453.55 7.00 -140.00 5,936,778.50 535,730.65 21 12,700.00 89.56 115.72 5,966.94 -7,578.72 5,817.26 9,546.81 7.00 -90.00 5,936,730.07 535,818.06 12,800.00 89.57 108.72 5,967.70 -7,616.50 5,909.78 9,634.99 7.00 -89.95 5,936,692.66 535,910.71 22 12,900.00 89.76 115.71 5,968.28 -7,654.28 6,002.30 9,723.18 7.00 88.50 5,936,655.25 536,003.37 13,000.00 89.95 122.71 5,968.54 -7,703.06 6,089.53 9,816.43 7.00 88.46 5,936,606.83 536,090.79 13,100.00 90.14 129.71 5,968.46 -7,762.09 6,170.16 9,913.37 7.00 88.44 5,936,548.12 536,171.65 23 13,200.00 90.14 122.71 5,968.22 -7,821.13 6,250.80 10,010.31 7.00 -90.00 5,936,489.41 536,252.51 13,300.00 90.13 115.71 5,967.98 -7,869.89 6,338.03 10,103.57 7.00 -90.02 5,936,441.00 536,339.93 13,400.00 90.13 108.71 5,967.75 -7,907.66 6,430.55 10,191.75 7.00 -90.03 5,936,403.60 536,432.59 24 13,500.00 90.13 115.71 5,967.53 -7,945.44 6,523.08 10,279.93 7.00 90.00 5,936,366.20 536,525.26 13,600.00 90.13 122.71 5,967.30 -7,994.21 6,610.31 10,373.18 7.00 90.02 5,936,317.78 536,612.68 13,700.00 90.12 129.71 5,967.09 -8,053.24 6,690.95 10,470.12 7.00 90.03 5,936,259.08 536,693.54 Planned TD at 13700.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,700.00 5,967.09 2 3/8" 2.375 3.000 4/3/2019 12:10:58PM Page 5 COMPASS 5000.14 Build 85D Pian Annotations Measured ConocoPhillips BAI(ER �, Conoco Planning Report i1UGI .NI -S +EI -W a GEmmpany Database: OAKEDMP1 Local Co-ordinate Reference: Well 2E-17 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project Kupamk 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-17L2 5,944.60 -4,673.07 Design: 2E-17L2_wP02 End 18 dls, Start 45 dls 8,943.38 Pian Annotations Measured Vertical Local Coordinates Depth Depth .NI -S +EI -W (usft) (usft) (usft) (usft) Comment 8,806.20 5,924.72 -4,659.89 3,414.62 TIP 8,807.00 5,925.35 -4,660.28 3,414.91 KOP 8,832.00 5,944.60 -4,673.07 3,424.44 End 18 dls, Start 45 dls 8,943.38 5,986.85 -4,752.65 3,483.73 End 45 dls, Start 7 dls 9,100.00 5,981.42 4,868.47 3,588.66 5 9,300.00 5,977.60 -5,019.67 3,718.77 6 9,550.00 5,973.36 -5,245.24 3,824.19 7 9,750.00 5,955.31 -5,428.92 3,899.93 8 9,950.00 5,937.66 -5,592.41 4,012.90 9 10,250.00 5,927.73 -5,850.20 4,162.71 10 10,500.00 5,924.53 -6,069.49 4,280.68 11 10,650.00 5,927.38 -6,180.55 4,381.15 12 10,950.00 5,936.20 -6,419.07 4,560.11 13 11,150.00 5,938.82 -6,585.86 4,669.55 14 11,345.00 5,933.17 -6,748.13 4,776.70 15 11,550.00 5,927.18 -6,917.97 4,890.39 16 11,950.00 5,961.18 -7,151.05 5,208.76 17 12,150.00 5,979.01 -7,244.48 5,384.12 18 12,350.00 5,977.69 -7,372.50 5,537.13 19 12,500.00 5,970.10 -7,472.72 5,648.19 20 12,600.00 5,966.18 -7,529.94 5,730.04 21 12,600.00 5,967.70 -7,616.50 5,909.78 22 13,100.00 5,968.46 -7,762.09 6,170.16 23 13,400.00 5,967.75 -7,907.66 6,430.55 24 13,700.00 5,967.09 -8,053.24 6,690.95 Planned TD at 13700.00 4/3/2019 12.10:58PM Page 6 COMPASS 5000.14 Build 85D �, ConocoPhillips BA ER ConocoPhillips Anticollision Report F IGHES BAT Company: ConocoPhillips Alaska lnc_Kupamk 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-171-2 Reference Design: 2E-17L2_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2E-17 2E-17 @ 146.00usft (2E-17) 2E-17 @ 146.00usft (2E-17) True Minimum Curvature 2.00 sigma OAKEDMPI Offset Datum Reference 2E-171-2_wp02 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,806.20 to 13,700.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum canter -center distance of 1,555.40 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Toot 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 13,700.00 2E-17L2_wp02 (2E -17L2) GCT -MS Schlumberger GCT multishot Summary Site Name Offset Well - Wellbore - Design Kuparuk 2E Pad 2E-01 - 2E-01 - 2E-01 2E-01 - 2E-01 - 2E-01 2E-01 - 2E-01 - 2E-01 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-06Li - 2E-061-1 2E -06 -2E -061-1-2E-0611 2E-06 - 2E-081-1-01 - 2E-0611-01 2E-06 - 2E-061-1-01 - 2E-061-1-01 2E-06 - 2E-061-1 PB1 - 2E-061-1 PB1 2E -06-2E-061-1 PBI -2E-061-1 PB1 2E-07 - 2E-07 - 2E-07 2E-07 - 2E-07 - 2E-07 2E-17 - 2E-17 - 2E-17 2E-17-2E-171-1-2E-171-1_wp03 Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usftl (usftl 8,824.98 8,825.00 8,824.98 8,825.00 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 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 0.51 -0.01 0.981 STOP Drilling, CC, ES, SF 0.51 0.14 1.385 Take Immediate Action, CC, Offset Design Kuparuk 2E Pad -2E -17 -2E -17-2E-17 greet site E.,.. e0a usft surcey Program: 158 -GCT -MS Onset Well Enon 000 ue11 Reference offset Semi Major Avs ol9ance Measured vertical Measuretl vertical Reference Ofrset Aiimith offset Welbme Centre Between BeMeen Minimum Separation Warem, Depth Depth Depth Depth from North .1415 E/ -W Centres Ellipses separation Factor (mm nut (usn) push) (ueh) (eshl (°) (craft) (uaf) (usnl pan) Krum 8,824.98 6,085.32 8.82508 60aSsG 801 0.24 -8465 4,609.04 3,42146 OS1 -001 0.52 0.981 STOP Drilling, OC, ES, SF CC - Min centre to center distance or covergent Point, SF - min separation factor, ES - min ellipse separation 422019 2:02:25PM Page 2 COMPASS 5000.14 Build 85D Q Lu r Eat sn ooS + 4uow - ylnos w� �r or J N 0 t C w w N m O t- caQvv o�NMQmm'mo+.. 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ZT IaZ..............t. C 6150 _ n _ 6000 5850 �, 5]00 _ 5550 W vii in .n r vi vi � b b Si (ui/)jsn oSl) 91daa leop"A ally I a ) m o clams # ( , / §y ! ` \ \ Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date EprE20x9] Well�� Coiled Tubing and 2-3/8" BHA Tree SizeE3 118 Quick Test Sub to Oti Top of 7" Otis Distances from top o Excluding quick -test Top of Annular Ci Annular Bottom Annular Flai CL Blind/Shears CL 2" COMb1 5 CL 2-318" Combi s CL 2" COmbl e CL of T( Top of CL SW Flow T CL SS CL K LDS n 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: (EXTERNAL14 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 loepp@alaska.l;aV> 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 LoeppO alaska aov 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 Victoria Loepp at (907)7931247 or Victoria Loeoo@alaska aov 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. Herrin era.conocoohillioscom ConocoPhillips Alaska 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.F.Herfing@conmophillips.com ConocoPhillips Alas"a 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@conocophill ips.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.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reee@alaska.gov. From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Monday, March 18, 2019 3:01 PM To: Regg, James B (DOA) <iim.reee@alaska.eov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Hobbs, Greg S <Gree.S.Hobbs@conocophillips.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) <jim.rePR@alaska.gov> Sent: Monday, March 18, 2019 2:45 PM To: Eller, J Gary <J.Gary Eller conocophillips.com>; Loepp, Victoria T (DOA) <victoria.Ice pp@alaska.Roy> Cc: Starck, Kai<Kai.Starck@conocophillips.com>; Hobbs, Greg S <Greg.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 !im.reggOalaska.gov. From: Eller, J Gary <1.Garv.Eller@conocophillips.com> Sent: Monday, March 18, 2019 2:26 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <iim.regg alaska.gov> Cc: Starck, Kai <Kai.Starck conocophillips.com>; Hobbs, Greg S <Greg.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 ConocoPhitlips 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, 2W 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 - 2'/" 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'/" a -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 — 2W 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%"-3Y=') 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 2W 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 2W 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 Ibf push/pull test to confirm the slips are holding. The push/pull test is Pagel 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 1 2" Pipe / Slip (Coil) 2'/." Pipe / Slip (Deploy) 2'/:' Pipe / Slip (Deploy) I Blind / Shear I 2" Pipe / Slip (Coil) Wing Valves Swab Valves Tree Flow Cross Equalize Surface Safety Valve Master Valve Choke Manifold 3 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 Annular fValves / Shear / Slip (Coil) lip (Deploy) Equalize s (2%"-3'/:") /Shear /Slip (Coil) Swab Valves Tree Flow Cross Surface Safety Valve Master Valve Choke Manifold 2 BOPS: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1116", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union r- --- - - - - ----- n N s_ y a a u Q £ E N N . D ® =I ¢W5 ou R o u a � _ o e e I e 4 t 2 r V � > s o u w MR n n £ Zg��H ED D TRANSMITTAL LETTER CHECKLIST WELL NAME: KR LL ;�,FF 17'L- a1. PTD: 2s' 1 9 — 0,915 Development _ Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: Kmpavak^t ✓ V POOL: �nav-u t< Al *Ve r 01 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 J LATERAL No. j99 — 1-7- API No. 50- 0 L1-14--oa-'aD 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 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 J 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 J 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#:2190550 Company CON_QCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 2E -17L2 Program DEV Well bore seg d❑ DEV/PEND GeoArea 890 Unit 1j.80 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 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 & wellbore cross-section views included 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 4/9/2019 14 Well located within area and strata authorized by Injection Order # (put 10# incomments)(For- NA - 15 All wellswithin1/4 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 Nonconven, gas conforms to AS31,05:0300.1.A),(y2.A-D) - - - - - - - - ---- - - - - - - - - - - NA. . 18 Conductor string. provided - - - - - - - - - ---- - - - - - - - - - - - - - - - ---------- - NA- - - - Conductor set for KRU 2E-17 Engineering 19 Surface casingprotects 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 completed with-unoemented slotted. liner 23 Casing designs adequate for C, T, B & permafrost - - - - - - - - - - ...... Yes - - - - - - - - - - - - - - - 24 Adequate tankage. or reserve pit - - - - - - - - .... - - Yes - - - Rig has steel tanks; all wasteto approved disposal wells - 125 If. a. re -drill, has -a 10-403 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 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 psig in comments). - - - Yes MPSP is 2804 psig; 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 presence of 1-12S gas probable . . . . . . . . . . .......... - Yes - H28 measures required - - - - - - - - 34 Mechanical condition of wells within AOR verified (For service well only) - - - NA. - - - - - - - - - - - ----- - - - - - - - - - - - - - - 35 Permitcan be issued w/o hydrogen sulfide measures No. 2E Pad -wells exceed. threshold. of 20 ppm in 20AAC25.065(a). reg. 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 - - - - - - 39 Contact name/phone for weeklyprogressreports [exploratory only]-- - - - - - - - - ----- NA Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Commissioner � y��