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215-146
RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 01 2019 REPORT OF ANNULAR DISPOSAL S 7-- ,v ex- �r cel , 1. Operator: 4a. Well Class: Stratigmphic ❑ Service ❑ 6. Permit to Drill Number: 215-146 l ' Af ConocoPhl lips as I rlC `" Development 2 Exploratory ❑ 7. Well Name: CD5-03 2. Address: 4b. Well Status: Oil Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20718-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final ❑r 315-762 / 316-469 / 317-451 1/8/16 & 1016/16 & 10/12/17 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement -contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 48746.74 5062 954 54762.74 57 11/2/2015 12/15/2017 CD5-10, CD5-07, CD5-01, CD5-08, CD5-12, CD5-17, CD5-314x, CD5-315, CD5-22, CD5-19 2018 / 1st 0 0 0 0 0 N/A N/A N/A 2018 2nd 0 0 0 0 0 N/A N/A N/A 2018 / 3rd 0 0 0 0 0 N/A N/A N/A 201814th 0 0 0 0 0 N/A N/A NIA Total Ending Report is due on the 20th Volume 48746.74 5062 954 54762.74 57 of the month following the final month of the quarter. Ex. (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. �1 Signature: !<, z,1,(- V Chip Alvord Date: E C ?j (t Zuf n Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE RMOS OL- /' F ? 0 6 7H 19 Submit in Duplicate ConocoPhillips Jan 30. 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Report, Fourth Quarter, 2018 - REVISED To whom it may concern: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 aryl rr r -m !: `vJ :v FEB 01 2010 11 e Please find attached the CORRECTED fourth quarter 2018 annular disposal reports for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2018, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2018. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. L. Alvord Alaska Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 215-146 ConocoPhillips Alaska, Inc. Development ❑� Exploratory p P ry ❑ 7. Well Name: CD5-03 2. Address: 4b. Well Status: Oil Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20718-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval roval date: � 9. Field: Initial Disposal ❑ or Continuation ❑� or Final ❑ 315-7621316-469/317-451 1/8/16& 10/6/16& 10/12/17 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement -contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred Fluids, formation fluids and any necessary water added Previous totals (bbls): 48746.74 5062 954 54762.74 57 11/2/2015 12/15/2017 CD5-10, COS -07, CD5.01, CD5-08, CD5-12, CDS-17, CD5-314x, CD5-315, CD5-22. CD5-19 2018 1st 0 0 0 0 0 N/A N/A N/A 2018 2nd 0 0 0 0 0 N/A N/A N/A 2018 / 3rd 0 0 0 0 0 N/A N/A N/A 2018 / 4th 0 0 0 0 0 N/A N/A N/A TOM] Ending Volume 48746.74 5062 954 54762.74 57 Report is due on the 20th (bbl5): of the month following the final month of the quarter. Ex. April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October October 20 for the third quarter, and January 20 for the Other (Explain) El quarter. 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Chip Alvord Date: Printed Name: G. 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EO o CM O g hi !llll n 3 UI Qr ~a O 3. w a raa) a. x o O N ▪ 00 -0 ,= 010) ❑ .mc ,z• iiiE O C 0. w oE BOG N -c 0 O N v m N N i U N U ❑ °� ea M 'V _ 0/ o co . 9• •O TO V O $ co To n c - 0 Q c c U E o 0 M �` n ti n bi g o Q g' c rt Pi o c o c ~w>-- . r _c in a r N M 0 N N N N ❑ — of • \ \I%:s, THE STATE. Alaska Oil and Gas �''�► iJ�� OfA LAsKA Conservation Commission �. : '= 333 West Seventh Avenue --w—* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O - Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 -� Anchorage, AK 99510 Re: Colville River Field, CD5-03 Permit to Drill Number: 215-146 � r � � Sundry Number: 317-451 s NES Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with therequirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, tSag\-- Hollis S. French Chair DATED this day of October, 2017. 11 2617 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 5 2017 ANNULAR DISPOSAL APPLICATION ars ),0AOGCC 20 AAC 25.080 1.Operator 3.Permit to Drill 13( Name: &45-146 ' ConocoPhillips Alaska 4.API Number: ! T w 50-103-20718-00-00 ' 2.Address: 5.Well P.O.Box 100360,Anchorage,Alaska CD5-03 6.Field: Colville River Unit- Alpine Pool , 7. Publicly recorded wells 8.Stratigraphic description: a)All wells within one-quarter mile: a)Interval exposed to open annulus: CD5-03, CD5-04, CD5-05, CD5-313, CD5-313PB1, CD5-07, CD5-09, CD5-10, CD5-314, CD5-315, CD5-315PB1, CD5-01, Torok and Seabee formation,shale,siltstone and sandstone CD5-02, CD5-21, CD5-08, C5D-12, CD5-06, CD5-99 CD5-20, CD5-17 b)Waste receiving zone: b)water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9.Depth to base of permafrost: 10.Hydrocarbon zones above waste receiving zone: approximately 1,342'MD and 1,320'TVD None 11. Previous volume disposed in annulus and date: 12.Estimated slurry density: 13.Maximum anticipated pressure at shoe: 45,107 as of 9/18/2017 densities range from diesel to 12#/gal 1929 14.Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids,cement- contaminated drilling mud, completion fluids,diesel,formation fluids associated with the 16.Estimated start date: act of drilling a well,drill rig wash fluids, cement rinsate,domestic waste water, any 6-Oct-17 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17.Attachments: Well Schematic(Include MD and TVD) Cement Bond Log(if required) ❑ FIT Records w/LOT Graph 0 Surf.Casing Cementing Data Other ❑1 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: '"isfir 1( Title: .61•1'1.11'D Printed Phone Name: Chip Alvord Number: 265-6120 Date: (2- Commission Use Only Conditions of approval: LOT review and approval: Subsequent form required: 10 ' 4 2 3 Approval number: 3 ‘7- f6 RBDr S u- CiCi 1 3 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 'o 11 i Ct-I t FgrrO 1/�(13 5fv.6 �, iR I n I 1ItITIONS ON REVERS ew cds)W 10;3.)2077 bmit in Duplicate ConocoPhillips Alaska,Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhi I i ps Telephone 907-276-1215 September 19, 2017 RECEIVED Alaska Oil and Gas Conservation Commission SEP 2 5 2017 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 AOGCC Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-03 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD5-03 (sundry permit#316- 469) be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD5, it is requested that the expiration date limit be extended)/CD5-03 was re-permitted for annular disposal of 70,000 bbls on October 6th, 2016 per Sundry#316-469. As—OT September 18, 2017, a total volume of 45,107 bbls has been injected into CD5- 03 for annular disposal. The projected volume that will be injected by the expiration date of October 6th is approximately 50,000 bbls which is well below the permitted volume of 70,000 bbls. The other wells not yet permitted for annular disposal are either in too close a proximity to upcoming wells or are not good annular disposal candidates. This leaves us with the choice of re-permitting a previously used annular disposal well to increase the allowable injection volume. Of the wells on the CD5 pad previously used for annular disposal, CD5-03 is a strong candidate for increasing the allowable injection volume. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. Increasing the allowable time for CD5-03 will allow for time to drill more wells and potentially other candidates for annular disposal. For further details,please reference the annular disposal permit for CD5-03, approved on October 6th, 2016. Please find attached form 10-403AD and other pertinent information as follows: 1. Copy of CD5-03 annular disposal permit#316-469. 2. List of wells on CD5 pad and the lateral distance from the surface casing shoe 3. Updated annular transmittal form 4. Additional information regarding wells within 1/4 mile radius that have not previously been submitted to the AOGCC If you have any questions or require further information, please contact Nina Anderson at 263-6403 or Chip Alvord can also be reached by calling 265-6120. v Sincerely, ,, '-` / /1-17(- /C/Vr Nina Anderson Drilling Engineer cc: CD5-03 Well File Chip Alvord • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 4 2016 ANNULAR DISPOSAL APPLICATION AOGCC 20 AAC 25.080 1.Operator 3.Permit to Drill Name: ' ,15-146 ConocoPhillips Alaska 4.API Number: 50-103-20718-00-00 • 2.Address: 5.Well P.O.Box 100360,Anchorage,Alaska cg.,V CD5-03 6.Field: Colville River Unit- Alpine Pool 7.Publicly recorded wells 8.Stratigraphic description: a)All wells within one-quarter mile: a)Interval exposed to open annulus: CD5-03, CD5-04, CD5-05, CD5-313, CD5-313PB1, CD5-07, CD5-09, CD5-10, CD5-314, CD5-315, CD5-315PB1, CD5-01, Torok and Seabee formation,shale,siltstone and sandstone CDS-02, CD5-21, CD5-08, C5D-12 and CD5-06 b)Waste receiving zone: b)water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9.Depth to base of permafrost 10.Hydrocarbon zones above waste receiving zone: approximately 1,342'MD and 1,320'TVD None 11.Previous volume disposed in annulus and date: 12.Estimated slurry density: 13.Maximum anticipated pressure at shoe. 25,374 as of 9/14/2016 densities range from diesel to 12#/gal 1929 14.Estimated volume to be disposed with this request: 15.Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud,drilling cuttings, reserve pit fluids,cement- contaminated drilling mud,completion fluids,diesel,formation fluids associated with the 16.Estimated start date: act of drilling a well,drill rig wash fluids,cement rinsate,domestic waste water,any 15-Oct-16 added water needed to facilitate pumping of drilling mud or drilling cuttings,and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17.Attachments: Well Schematic(Include MD and TVD) 11] Cement Bond Log(if required) ❑ FIT Records wlLOT Graph 0 Surf.Casing Cementing Data Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: L.- - Title: `,r ittt (^° Printed Phone Name: Chip Alvord Number: 265-6120 Date: ti i4.(14 Commission Use Only Conditions of approval: LOT review and approval: C� Subsequent form required: "B 42 3 Approval number: �,� '4(J ` APPROVED BY Approved by: / P COMMISSIONER THE COMMISSION Date:/6_6_/4 Form 10-403AD - v.6/2.04 1 l n 1 I r-rne 1hYS ON REVERSE Submit in Duplicate 1 r . 1 11 I : 111,111.414,,11.1., _ v.I. i L !A:4_,., ,N,. ,111:1! 7 1,10 ii: 11 610 ,411! !..:4 . t5 -1 M 0 m3 1 p g ,;1.1 I . ll '• • FwbM1 ' 11111 pmw co -1 i P :: : 4 g 9 - Nil i i ,...,, ,...,. . „,,..„ : ...... -: : 6:Ii.. 0 ' 1 , ! 'PY' '' I i : i p,E., 40, !,..:-. I I klIN mm„ U2iN d Hlc; N C1. C+k FLLIIIIII 9s-ti. Ai '''' R cn111 a R M 111 Pia Os mi E V O m'0Tr G s. 3 ci, — '",.? N o , _., LI V 0` LO -ON1 EUFULLFF11I L o 07 iril ii * ii Nd)o CEN — — to ip.Ili 11111 II , Q 1 1211 II —pi . 0 p 271 D ,.. ,. t,..1 ril 1 Ili 2 ..0 ,cs i-,- 0 0 1 I! 1 II ce ,s, co ; : I:I:1: • "41.-- o••,'M IA Or II R kik" Q Q j x 1 !PIFIiiILLL W V N Q W C Fw21:1.1 1:11 ri Ilr:74.‘ki7: i'4'''''' .r'''1. '. 4'7 �7,5 �O O II 1 O O O O 111111111 O �IM iht ci is 1iILIII1III. Ii!P rn W . 14110 N N co N 1IIIIlI1III1IkI1 aC c8i d .1k! ' C lir. : UUani QG �... i171 1 ! i :' iIFF C L 111 O and W(") ® I� Nr�-OD NOCl100 OI�v N O aF;o oo omr N �t[) tri to 7Ci in uz u"try:0 0 in CI 00 0 _0 . 00.000®0 t0E 0 U U,"`U UtTUCU`>;UlUc?U3 zJ • • Annulus Disposal Transmittal Form - Well CD5-03 AOGCC Regulations,20 AAC 25.080(b) 1 Designation of the well or wells to receive drilling wastes: CD5-03 2 The depth to the base of freshwater aquifers and permafrost,if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost= 1320' TVD(RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref.AOGCC Conservation Order No.443, March 15. 19991 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud,drilling cuttings,reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids,diesel,formation fluids associated with the act of drilling a well,drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 70,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate,mud plant rinse fluid generated by rinsing waste under(h)(3)of this section. tanks and equipement after producing drilling/completion fluid(see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1929 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports,LOT/FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones,if any above the The top of cement is 6877'MD in the intermediate casing depth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this depth 12 The duration of the disposal operation,not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so,a summary of the dates of the disposal operations,the volumes of waste disposed of,and the wells where the drilling waste was generated. 14 The well(s)where the drilling waste to be disposed of was or CD5-316, CD5-22,CD5-24,CD5-19, CD5-25,CD5-23 along will be generated. with future planned wells on CD5 15 If the operator proposes not to comply with a limitation N/A established in(d)of this section,an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • Attachment A Additional Information regarding wells within 1/4 mile radius that have not been previously been submitted to the AOGCC • CD5-99 o Surface Casing Tally o Intermediate Casing Tally o Daily Drilling reports from Casing and Cement both Surface and Intermediate o Cement Detail Reports for both Surface and Intermediate o 10.75 Surface FIT o 7.625 Intermediate FIT/LOT o 10.75 x 7.625 AD LOT • CD5-17 o Surface Casing Tally o Intermediate Casing Tally o Daily Drilling reports from Casing and Cement both Surface and Intermediate o Cement Detail Reports for both Surface and Intermediate o 10.75 Surface FIT o 7.625 Intermediate FIT/LOT o 10.75 x 7.625 AD LOT • CD5-20 o Surface Casing Tally o Intermediate Casing Tally o Daily Drilling reports from Casing and Cement both Surface and Intermediate o Cement Detail Reports for both Surface and Intermediate o 10.75 Surface FIT o 7.625 Intermediate FIT/LOT o 10.75 x 7.625 AD LOT • • Additional information regarding CD5-99 S CD5-99 10 3/4"Surface Casing Well: CD5-99 10-3/4" 45.5# L-80 BTC & H d 563 Casin. Date: 8/30/2016 ConocoPhillips Rig: Doyon 19 Alaska,inc. Depth Jt Number Joints .�.. 4 Well Equipment Description and Comments 01 Length Tops Page 1 RKB to Top or:warm . ciffrfRkg to Lack Dcwin$crews'. Doyon 19"RKB'=tbtop of Landing Ring -"_ , 36.00 FMC 10-3/4" Casing Hanger .18 36.00 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt, Pin X Pin 2.24 36.18 Jts 4 to 55 52 Jts 10-3/4", 45.5#, L-80, HYD563 DPLS Casing 2099.26 38.42 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt 28.73 2137.68 10-3/4", 45.5#, L-80, BTC Pin X HYD563 Box Casing XO Jt 42.73 2166.41 Jts 3 to 3 1 Jts 10-3/4", 45.5#, L-80, BTC Casing 41.54 2209.14 10-3/4" HES Float Collar 1.23 2250.68 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC Casing 82.53 2251.91 10-3/4" HES Composite Shoe 2.70 2334.44 2337.14 2337.14 2337.14 2337.14 2337.14 2337.14 2337.14 2337.14 10-3/4" Shoe at 2,337' MD /2,182' TVD 2337.14 13-1/2"TD at 2,347' MD / 2,189' TVD, 10' rathole 2337.14 2337.14 2337.14 2337.14 1 Centek 10' up from shoe w/stop rings on Jt#1 2337.14 1 Centek 30' up from pin w/stop rings on Jt#2 2337.14 1 Centek 20' up from pin w/stop rings on Jt#3 2337.14 1 Centek every joint from #4 to#53 Floating 2337.14 2337.14 1 Bow Spring floating on jnts 54-55 2337.14 2337.14 Total Centralizers = Centeks 55, Bow springs 2 2337.14 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2337.14 2337.14 2337.14 2337.14 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 142 K MU Tq with Volant- 16.2 k ft/lbs trq for Hyd 563 and 19.2K ft/lbs on dopeless Down Wt 131 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:R. Bjorhus/R. Reinhardt/G. Whitlock • Security Level: AK Development Daily Drilling Report (No Costs CD5-99 t�txtocoPtti[la Report Number: 3 Rig: DOYON 19 Report Date: 8/29/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99 Development 1.60 3.0 765.00 1,582.0 2,347.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 54.68 0.27 10/20/2016 Last Casing String CONDUCTOR, 115.0ftKB Ops and Depth @ Morning Report 24hr Forecast Running 10%"casing @ 1,900'MD Run and cement surface casing,shut in and monitor 12 hrs.Perform any maintenance/insp due,prep for intermediate. Last 24hr Summary Continue drilling 13W Surface section to TD 2,347'.Condition and POOH.L/D BHA,R/U and run 10%"casing. General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. Fog/Mist,36°F,Wind E 14 mph,WC 27,Vis 61.0 2.5m Supervisor Title Rick Bjorhus Rig Supervisor Guy Whitlock Rig Supervisor Rob Reinhardt Rig Supervisor Joseph Engel Rig Engineer David Lee Drilling Engineer Time Log • ;- StartTime End Time Dur(hr) - Phase z, Op Code Activity Code -,-T-X Trbl Code Trbl Class Start Depth(ftKB)' End Depth(ftKB) --Operation 00:00 02:00 2.00 SURFAC DRILL RGRP T Rig Solids 1,582.0 1,582.0 Due to heavy buildup of sticky Control clay in bottom of drag chain trough,had to change out to a harder paddle to scrape trough. After changing paddle,had to clean out the drag chain trough of clay by scraping/chipping so harder paddle would pass.In the proccess,the drag chain switch broke,electrician repaired while floorhands cleaned out the trough. 02:00 11:30 9.50 SURFAC DRILL DDRL P 1,582.0 2,347.0 Directional drill from 1,582'MD to 2,347'MD,2,189'TVD. ADT=6.56,AST=2.51,ART=4.05. P/U=125k,Jar Hrs=13.05. 5/0=120k,ROT=120k,TQ on/off=6k/4k.580-800 gpm,2600 psi. Weight up mud system to 9.6 ppg @ 1,900'MD,then 10.0 ppg by TD. 11:30 12:00 0.50 SURFAC CASING CIRC P 2,347.0 2,246.0 Pump survey on bottom,pump weighted sweep with Nut Plug M. CBU 358 bbl,lay down single and rack back 1 stand. 12:00 14:15 2.25 SURFAC CASING CIRC P 2,246.0 1,772.0 CBU X 4,racking back stand after each BU from 2,246'MD to 1,772'MD at full rates 800 gpm, 2360 psi,60 rpm,3k Tq. 14:15 14:30 0.25 SURFAC CASING OWFF P 1,772.0 1,772.0 Flow check well for 15 minutes, static. 14:30 15:15 0.75 SURFAC CASING TRIP P 1,772.0 1,488.0 POOH on elevators from 1,772' MD to 1,488'MD.Pulling over 25k @ 1,609',1,602',1,519°, 1,488'.Decide to pump out. Latest BOP Test Data Date i >r Corn Page 1/3 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Cost > ' 1r. CD5-99 tilf cxiocc>Pttilti�es Report Number: 3 t,i:xkx Rig: DOYON 19 Report Date: 8/29/2016 Drilling Parameters .., n : y . FlowRatE End r Sliding (9 ' 14, ' RPDAtilWW fit 1, "1 i IStrWt SO Sir Wt 1 i Start(ftKB) V', (fittG9} ;a ..,�8pth(R) _ Cum Drill Time(hi): Time hr (9,. ..,i t7rX11b (rpm} '. SPP• si�;!��,,n a a,� t (1000Ibf} -(•� 1 #3tr8iRlTEt. :. ,.�, • 1,582.0 2,347.0 2,232.00 15.20 2.51 800 30 50 2,600.0 125 120 120 4.0 6.0 t. 2,347,0 2,347:0P,J,,,;2 •.- :15.20 Interval Problems Start pate Stott Depth:i,i°t ..;; , End Depth(ftKB} ......Tr ,code Trouble Class Welhore 8/29/2016 1,582.0 1,582.0 Rig Solids Control CD5-99 /c '.' r,../Oil,, Wellbore Name Wellbore API/UWI CD5-99 501032074800 o; otr Des.. : Size(m) _•••••; , Act Tap MB}' AM Bun(f1<8)> ,„?,r,,,,,'IVA<y...iiiiiiiiiStart Date End Date f, CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM1 11 2,347.0 17,049.0 9/1/2016 10/1/2016 Survey Datil ;t • c.. 400, ; KB} Incl(} 4t,, ',h} ht(*) • TVD(IIIS} ....... .,, VS'(ft) . ,arfOiRag S. } EW(fi} 0LS , 1,600.00 23.81 137.20 1,569.89 229.36 -201.47 109.65 3.24 1,694.62 26.66 133.78 1,655.48 268.00 -230.17 137.96 3.38 1,788.88 29.81 132.16 1,738.51 310.14 -260.54 170.60 3.44 1,882.94 32.44 130.76 1,819.03 355.65 -292.71 207.05 2.90 1,976.80 33.94 130.25 1,897.58 403.46 -326.08 246.12 1.63 2,070.83 35.82 129.12 1,974.71 453.19 -360.40 287.51 2.11 2,165.49 37.79 127.90 2,050.49 505.19 -395.70 331.88 2.22 2,259.48 40.14 127.23 2,123.57 559.00 -431.72 378.74 2.54 2,270.51 40.86 126.48 2,131.96 565.48 -436.02 384.47 7.89 Page 3/3 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report(No Costs ' ►'� ., � CD5-99 cartom) f[li Report Number: 3 Rig: DOYON 19 Report Date: 8/29/2016 Time Log .. StartTime E d Time Dur h Phase :: O Code Actin Code. T X ( � P fty Trbl Code Phi Class ftK6 start'De th Depth( } End Depth(RKH) ' • � • Operation - .- 15:15 16:00 0.75 SURFAC CASING PMPO P 1,488.0 1,300.0 Pump out of hole from 1,488'MD to 1,300'MD @ 550 gpm,1260 psi,no rotary. 16:00 18:00 2.00 SURFAC CASING TRIP P 1,300.0 84.0 POOH on elevators from 1,300' MD to 84'MD.Observed tight spot @ 312'MD,25k overpull. Worked it twice,third time pulled trough no more overpull. 18:00 20:00 2.00 SURFAC CASING BHAH P 84.0 0.0 PJSM,lay down BHA per SLB DD/MWD reps.Clean and clear rig floor. 20:00 21:30 1.50 SURFAC CASING RURD P 0.0 0.0 P/U and R/U Volant CRT,bail extensions,hand slips,bowl inserts,103A"elevators and casing equipment,350T slips, 10%"Hanger. 21:30 21:45 0.25 SURFAC CASING SFTY P 0.0 0.0 PJSM on running 10%"casing with DDI,CPAI,Doyon casing. 21:45 00:00 2.25 SURFAC CASING PUTB P 0.0 481.0 Pick up shoe,shoe track,Float collar and XO jt.Flow test through floats and check floats OK.Continue P/U 10%"Hydril 45.5#563 casing to 481'MD Mud Check Data '' YP CalcGel(10s) Gel(10m) `- Gel(30m) HTHP Filtrate Density Temp Solids,Co , Type Depth(EKE) Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') (I13000(?) (ib(/100ft') (Ibf/100fe) MET(Ib/bbl) (mL130min) pH [('F) ;i(%) DRILPLEX 2,347.0 10.00 12.0 31.0 32.0 46.0 60.025 15.0 0.0 10.9 76.0 9.0 DRILPLEX 2,347.0 10.00 8.0 47.0 46.0 49.0 52.021 15.0 0.0 11.0 86.0 9.0 DRILPLEX 2,211.0 9.60 10.0 36.0 38.0 41.0 43.018 12.0 0.0 11.0 72.0 7.0 DRILPLEX 1,679.0 9.25 6.0 50.0 39.0 40.0 41.017 12.5 0.0 10.8 56.0 6.5 Drill Strings: BHA No.1 - Steerable'/ Bit Run No..1 13 1/2in,VM-3,_5260390' Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(ins) Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 115.0 2,347.0 0.76 15/16/16/16 2-4-WT-G-E-2-PN-TD 33 Drill String Components Jts Item Des OD-(In)„ ' ID(In)'- Top Conn Sz(in) - Top Thread Cum Len(ft) 8-1/4"PDM 8 1/4 2.125 6 5/8 Reg 32.85 12 1/8"NM Stabilizer,Ported float 8.35 2.880 6 5/8 Reg 40.22 1 8"Pony Drill Collar 8.35 2.875 6 5/8 Reg 50.25 1 8"Pony Drill Collar 8.3 2.875 6 5/8 Reg 60.30 1 8 1/4"MWD 8.35 5.900 6 5/8 Reg 89.22 8 1/4"NM UBHO 8 1/4 2.875 6 5/8 Reg 92.93 8 1/4"NM XO 8 1/4 2.880 4 1/2 IF 95.96 1 6 7/8"NMDC 6.7 2.875 4 1/2 IF 127.01 1 6 7/8"NMDC 6.85 2.875 4 1/2 IF 157.55 7"Saver Sub 7 2.810 4 1/2 IF 160.74 13 5"HWDP x13 5 3.000 4 1/2 IF 559.43 1 Drilling Jars-Hydraulic 6 1/4 2.250 4 1/2 IF 589.12 8 5"HWDP x 8 5 3.000 4 1/2 IF 832.85 49 Drill Pipe 5 4.276 4 1/2 IF 2,347.00 Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report ort (No Costs M, CD5-99 ConocoPhilli Report Number: 4 Rig: DOYON 19 Report Date: 8/30/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99 Development 2.60 4.0 0.00 2,347.0 2,347.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 54.68 0.27 10/20/2016 Last Casing String SURFACE,2,337.1ftKB Ops and Depth @ Morning Report 24hr Forecast P/U 5"DP&Rack Back in Derrick M/U BHA#2.P/U&rack back 5"DP.N/D riser&annular.N/U BOPE&MPD.Test BOPE.RIH w/BHA#2&drill out Last 24hr Summary Run 10 3/4"casing&land on hanger 2,337.Circ&cond.Cement as per Dowell.W.O.C. Perform top drive maintenance.Pit&shaker modifications. M/U BHA#2 &rack back in derrick. General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. Fog/Mist,51°F,Wind NW 3 mph,Vis 10.0 53.0 Supervisor 'Title Guy Whitlock Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer David Lee Drilling Engineer Time Log , Time P Start Time End Time Our(hr) .1PtaSe�i- ,,,,iOpCede" �ActivityCode '-T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth MKS) Operation 00:00 03:45 3.75 SURFAC CASING PUTB P 481.0 1,489.0 Continue running 10'/"45.5#L- 80 Hydril 563 casing from 481' MD to 1,489'MD(Jt 35).Took weight to block weight @ 880' MD,repeated attempts to pass past 900'very slow.Establish circulation @ 2 bpm,increased to 3 bpm and washed down joint #21. 03:45 04:30 0.75 SURFAC CASING CIRC P 1,489.0 1,489.0 CBU(110 bbl)@ 1,489'MD, stage pumps up from 3 bpm to 5 bpm. 04:30 07:15 2.75 SURFAC CASING PUTB P 1,489.0 2,299.0 Continue running 10'/,"45.5#L- 80 Hydril 563 casing from 1,489' to 2,299' 07:15 07:45 0.50 SURFAC CASING HOSO P 2,299.0 2,337.0 M/U hanger&landing joint.Land casing on hanger @ 2,337'.PU wt 142 k,SO wt 131 k 07:45 09:45 2.00 SURFAC CEMENT CIRC T Fluids Rheology 2,337.0 2,337.0 Attempt to establish circulation. Pumping 1 -3 bpm @ 480 psi on the up stroke&pumps off on the down stroke.No returns on the down stroke.Cont to reciprocate pipe&circ out thick heavy mud for a total of 200 bbls pumped before full returns were established. 09:45 12:15 2.50 SURFAC CEMENT CIRC P 2,337.0 2,337.0 Circ&cond mud for cement job. Stage pumps f/3 to 8 bpm.ICP 480 psi&FCP 150 psi.PU wt 142 k,SOwt131k 12:15 12:30 0.25 SURFAC CEMENT RURD P 2,337.0 2,337.0 B/D top drive&R/U cementing lines. 12:30 13:00 0.50 SURFAC CEMENT CIRC P 2,337.0 2,337.0 Break circ thru cemtnlines w/8 bpm @ 420 psi.PJSM on cementing. Latest BOP Test Data Date . . , Corn Page 1/3 Report Printed: 9/25/2017 Security Level: AK Development � Daily Drilling Report (No Costs) CD5-99 ConacoPhii!i Report Number: 4 Rig: DOYON 19 Report Date: 8/30/2016 Time Log Start Time End Time Dur(hr); Phase Op Code •Activity Code `T X 'Trbl Code Trbl Class StartDepth(ftKB) End Depth(ftKB) Operation 13:00 16:00 3.00 SURFAC CEMENT CMNT P 2,337.0 2,337.0 Dowell PT lines to 3500 psi, Dowell pump 75 bbls 10.5 ppg Mud Push II w/5 bpm @ 165 psi, Drop btm plug,Dowell pump 288 bbls 11.0 ppg(846 sks-1.91 yld LiteCrete)lead cement w/5 bpm @ 300 psi,Dowell pump 50 bbls 15.8 ppg(240 sks-1.17 yld Class G)15.8 ppg tail cement w/5 bpm @ 350 psi,Drop top plug,Dowell pump 20 bbls water, 5 bpm,350 psi,Rig chase with 197 bbls 10.0 ppg DrilPlex mud w/8 bpm @ 800 psi,slow to 3 bpm @ 450 psi last 10 bbls,and bump on schedule with 1952 stks @ 96%eff.Pressure up to 950 psi&hold for 5 min.Check floats (good)CIP @ 15:52 hrs. Reciprocate pipe w/full returns. • 165 bbls good cement to surface. 16:00 16:15 0.25 SURFAC CEMENT OWFF P 0.0 0.0 OWFF static,Function 20" annular 3 x(Flush with 35 bbl treated water)Leave annular closed&monitor psi. 16:15 18:00 1.75 SURFAC CEMENT RURD P 0.0 0.0 Rig down cementing equipment, clean and clear rig floor.Break off 10'pup from 2 piece landing joint. 18:00 22:00 4.00 SURFAC CEMENT WOC P 0.0 0.0 Mechanic inspect&service IBOP.Install new sensor for MWD on stand pipe.Test stand pipe to 5000 psi.Test IBOP to 3500 psi.Check pre-charge on hydraulic accumulator on top drive.SIMOPS-W.O.C.&clean pits. 22:00 00:00 2.00 SURFAC CEMENT WOC P 0.0 0.0 M/U BHA#2 as per SLB&rack back in derrick.SIMOPS- W.O.C.&clean pits. Mud Check Data YP Calc? Gel(10s) Gel(10m): Gel(30m) . HTHP Filtrate Density Temp Solids,Corr., Type Depth(ftKB) Dens'(lb/gal) Vis(s/qt) PV Calc(cP) (lbf/100ft')` (lbf/1 O0fF) (lbf/f 00ft') S (Ibf/100ft2): MST(Ib/bbl) (mL/30min)- pH ('F) (%) DRILPLEX 2,347.0 10.00 13.0 10.0 3.0 3.0 3.001 12.5 0.0 9.5 60.0 9.0 DRILPLEX 2,347.0 10.00 12.0 18.0 16.0 21.0 24.010 11.0 0.0 10.6 66.0 8.5 DRILPLEX 2,347.0 10.00 14.0 38.0 41.0 46.0 48.020 15.0 0.0 10.7 64.0 9.0 DRILPLEX 2,347.0 10.00 8.0 59.0 56.0 62.0 62.026 15.0 0.0 10.8 67.0 9.0 Injection Fluid = +. s . Fluid Source From Lease(bbl) Dest = Vendor- Manifest Number , r Note . Cementing Fluids CD5-99 965.0 CD5-11 CD5-99 Cementing Fluids Diesel 5.0 CD5-11 Injectivity Test Drilling Mud WBM CD5-99 349.0 CD5-11 CD5-99 displacement Mud Fresh Water 20.0 CD5-11 H2O Spacer Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development 9' 4 Daily Drilling Report (No Costs CD5-99 4 Report Number: 4 ConocoPhillips • Rig: DOYON 19 Report Date: 8/30/2016 Di t Strings:•DHA No.2 -, Steerable C Brt,Run,No 2, S9 7/8irt,MD,16,1,6HESPXC,JM3082"'f,,,,,,, I ' ,-. ,, : , ,„ . Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in2) Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 2,347.0 17,049.0 0.84 11/11/11/11/11/11/11/11/11 1-2-CT-S-X-l-NO-PR 347 Drill String Components .'its ldinOinirMRS ..= Item;,Des 7.,, .;_?__,:;0 k, OD(s1Y a Z1;',.0::1 Top CoenSz;(In)I- arOilitteatt.:. - Cutnten(ft) 6 3/4"Xceed 7 2.810 5 1/2 FH 25.96 6 3/4"Periscope 6.89 2.810 5 1/2 FH 46.94 6 3/4"Telescope 7.89 3.880 4 1/2 IF 74.91 Steel Float Sub(NPFV) 7 2.875 4 1/2 IF 78.48 9 3/4"NM Stab 6.85 2.875 4 1/2 IF 85.64 7"Pony DC 7 2.875 4 1/2 IF 95.74 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 106.72 Float Sub(NPFV) 7 2.875 4 1/2 IF 109.53 1 7"NMDC Corrosion ring 6.7 2.875 4 1/2 IF 140.58 NM Stabilizer 6.85 2.875 4 1/2 IF 147.79 1 7"NMDC 6.85 2.875 4 1/2 IF 178.33 Saver Sub 7 2.750 4 1/2 FH 181.52 12 HWDP 5 3.000 41/2 IF 549.39 Drilling Jars-Hydraulic 6.2 2.250 4 1/2 IF 579.40 8 HWDP 5 3.000 41/2 IF 823.13 518 Drill Pipe 5 4.276 4 1/2 DS 50 17,049.00 Drilling Parameters Flow Rate 1gpm}' WOB` RPM PU Sf Wt. DtlItStr Wt Start(ftKB) (RIKB)•• .,;,tom Depth(ft) Cum MTh Ttme(hr} (try tgpm) (1�f)�I ; 'pm) :3, PP Opwt#,_ ::('t Nbf). (R tbt) (1000lbf) Off Ben Tq Drill Tq ...::.i 2,347.0 2,347.0 Weilbores ...gi '•i1 rlif3'., Wellbore Name Wellbore API/UWI CD5-99 501032074800 Section Des `Size(in) ..Act-TOp(ft1(8) .�• Act Btm(ftKB) Start Date', - End Date'. CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM1 11 2,347.0 17,049.0 9/1/2016 10/1/2016 Casing Strings,.. ,.,w A Csg Des r ,,,.i Run Date„ OD tin) WI/Len(lb/ft) Grade v Set Depth(ftKB) ''.�..-.'• ' Com SURFACE 8/30/2016 10 3/4 45.50 L-80 2,337.1 Cement ; Surface Casing Cement -Started @ 8/30/2016 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-99A SURFACE,2,337.1ftKB 165 bbls good cement to surface. Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.6 2,337.1 3 420.0 Fluid S s',,, , ,.t' Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal), y Yield(fN/sack) Est Top(ftKB) Est elm(1 ) � Lead Cement LiteCRETE 846 288.0 11.00 1.91 36.6 1,837.0 Tail Cement G 240 50.5 15.80 1.16 1,837.0 2,337.1 Page 3/3 Report Printed: 9/25/2017 CD 0 0 • LO LO LO LO LO LO LO u) Ln Ln LO LO LO LO -t NI- �t . Co Co Co Co Co Co Co Co Co Co Co Co Co Co CO 070) 0) 0) - CT 0) 0 00D0) o CAo000) 0) 00 •' Y �+ • C) U Cl a) fa • C) d = m u X NLE c ~ O u) 00 0000 000 O 0000000000 p I N (6 LL E r_+ CD N LO C] LO C] Ln 0 LC) o LO o LO o Ln o LI) o LO o LO o > d x EC a - L o o o c- c- N N M M ,i LO LO (O CO I� I� 00 00 0 0 o Cm - C E- m _ n cn a 0 0000 0000 000 LC) * � r�: ch CON Co Co (0 P. t` CO r Ln % p> N b 0 N .Q N co V Lf) CO N- Co 0) a / C d Di 0 C ' aE.. 0 NM � COCON- 00070 c- 3 E 0 7 O �. a a � L .a) (n T a) U 0, co t N 47:. _ 0oo000 oo oLOooO L0 ooo 1"1"""'''dVa) c "' CO CO (0 (0 L) L) LO LO LfLO LO LO LO 10 £ -;79m - MM0000 00M000MMM M M0001 E o u O I T. m O• O ' - O c'111/1111(°11 " 0OJ 0 O O O ii 111 O 37 A w! C 0000 0000 000 0 00000000 -n 7 .N O O LO Lf) O O LC) O Ln Lf) Lo O O LC) O O Lf) O O N n 0. co N . co LC) co 0 .- N cY LC) N- 0) co LC) CO O N LO (.O 0 ;, - (,) .0 ,- v- V- c- V- ,- V- NNNNCoC7MM E N ci E...... E co O CV ..' CO 000 N d' (0 Co 0 N •d' (0 CO O CV t CO I,- p .n D1 c- ,- ,- <- ,- N N NNNMMMMM 0 7� v d }L, > a • - - N F- a k .0,'Ea.:... N I I I I F > V c0 .0 a I F ca F- _ N 0_ LL LL 0 O = Cl0 ca N a)) rn a ° M o C) o 0 o c LL Q .O C) N a.., QJ JJ Q. a p ai o c 0 N Coo * OOM I- E 'C LLJ a. N m _ F- Oi I,- ltOc• o Off a .N . >_' C �' ci yk O >. k o c O ar o C o F _ * oo a) Cl •• Lr M EL- WN = 0 0 v C C) _C -. N J pry, 0 :. ,D,^ U a a N N •- LO �• • V! 0 E E p N -60 0 > a '�' O) • v V) Z 0) if a d c to + . W — - o -0 m 0 0 a Q co N O ' O O co O ~ U in C) +'' N O° Co 0 tu' m o w •,, O. C) 0 LO X 11 F L Q CNO' 2.., m LN ^� L.L. 0 L Q 0 d N0Y .- L — L._> W 65 0 Cr)ii LL L CO U Ci m k..' N T O csI co O •R -1 LL r Q V N 11 Cs1 En_ CO• CO) a.+ 0 `� d .t' C- F N Q_o 'u) � .o .0m L 0)o o_...) O.J J . •E , LO - -' C 1- 0 0 0 (O LL m u) F- o d 0 M O O NU L L Ln o L u) M oo E M F __ ;7, a r lL 0 N 4t O N U co co 0 — `^ y F- + Z 0 LC) CD c� a) L rnN L0 c'"6 - ¢ ,-- rn N c to N O ~ N U Q Q. Lo U Ec ;v p L X E \ f o 0 L: N f. 0) -p n_ m > w a N W LO co O of - 30 C • U) 4,_ lig IMr- a a) U •N t y w 7 0. co N J o 0 0 0 0 0 0 0 0 U) �' ?,'4 C 0 .. w 0 t)i 0 0 ) o C Z ~ in ce 0 11 M M N N m 3 iflSS id E TD o E o 0 I w 0 Cement Detail Report CD5-99 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/27/2016 00:00 Cement Details 1,,r k ,,,, „h„ Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/30/2016 13:00 8/30/2016 16:00 CD5-99A Comment Cemented with full returns. 165 bbls good cement to surface. Cement Stages �' •r,„ -, ,,,NOW44 Stage#1 ^� 3 ��� 3�3 a•:• ., • •••161111 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 36.6 2,337.1 Yes 165.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 6 420.0 950.0 Yes 8.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement L IttidS&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.6 1,837.0 846 LiteCRETE 288.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.79 0.00 11.00 220.0 5.50 50.0 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Conc Unit label D167 0.5 %BWOC Additive Type Concentration Conc Unit label D185 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,837.0 2,337.1 240 G 50.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 0.00 15.80 102.0 5.00 200.0 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Conc Unit label D065 0.3 %BWOC Additive Type Concentration Conc Unit label D167 0.4 %BWOC Page 1/1 Report Printed: 9/25/2017 • S CD5-99A_7-5/8"Intermediate casing Well: CD5-99A ConocoPhillips 7 5/8"29.7#L80 BTC-M & Hyd 563 Dopeless Casing Date: 10/13/2016 Alaska,Inc. Rig: Doyon 19 Depth Num Jt Number of Jts Well Equipment Description and Comments Length Tops Fill Page 1 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS , .. . ``*W 34.05/ .... / �� ;9 FMC 7.625"fluted hanger .72 ,. 34.05 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.31 34.77 Jts 328 to 386 59 Jts 7-5/8", 29.7#, L-80 H563 Dopeless Casing 2368.41 37.08 7-5/8", 29.7#, L80 XO jt , H563 DPLS box X BTC pin 39.01 2405.49 Jts 221 to 327 107 Jts 7-5/8", 29.7#, L80, BTC-M Casino , 4263.97 2444.50 " t �� ,,, ttteir'Bt "� rte base6 66$1 Oa t ti 6E8$$- 3.08 , i1'', Jts 16 to 220 205 Jts 7-5/8", 29.7#, L80, BTC-M Casing 8180.95 6711.55 7-5/8", 29.7#, L-80 BTC-M Pup Joint 6.06 14892.50 7-5/8", 29.7#, L80, BTC-M Casing with RA Tag in Coupling 40.26 14898.56 Jts 14 to 15 2 Jts 7-5/8", 29.7#, L-80 BTC-M Casin• 82.41 14938.82 Jts 13 to 13 1 Jts 39.35 Jts 8 to 12 5 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 203.72 15060.58 7-5/8", 29.7#, L-80 BTC-M Pup Joint 20.12 15264.30 Jts 5 to 7 3 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 118.89 15284.42 7-5/8" HES Baffle Collar 1.20 15405,31' Jts 3 to 4 2 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 80.94 15404.51 7-5/8" HES Float Collar 1.25 1; 154854,5 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC-M Casing 81.23 15486.70 7-5/8" HES Eccentric Nose shoe 2.65 15567.93 557Q5 Alpine C Top 15,031' MD /7,481' TVD 15570.58 TD 9-7/8" Hole at 15,582' MD/7,566' TVD (11" Hole to 15,477') 15570.58 Casing Shoe at 15,570' MD/7,565' TVD 15570.58 15570.58 1 Hydroform 10' up from shoe w/stop ring on Jt#1 15570.58 3 Hydroforms per 2 joints from #2 -#10, stops at 27', 13' as per schedule. 15570.58 1 Hydroform on jt#11  w/stop ring 5'from pin 15570.58 • 15570.58 1 Hydroform on jt#14 above stop ring 5'from collar 15570.58 3 Hydroforms per 2 joints from #15 -#44, stops at 27', 13' as per schedule. 15570.58 1 Hydroform per joint floating from #220-#240 15570.58 1 hydroform on every joint#328 -#33015570.58 1 Straight Blade Centralizer on every other joint from #331 -#385 15570.58 118 Total Centralizers(Hydreforms=90, Straight blades=28) 15570.58 Remarks: 9-5/8"OD hydroform centralizers Baker Lock shoe track to pin of joint#5 Up Wt K Baker Lock stage collar&pin of joint#221 Dn Wt K M/U Tq for 7-5/8" HYD563 DPLS 12,400 ft/lbs Block Wt 60 K Avg. M/U Tq for 7-5/8" BTC-M w/Volant=8,100 ft/lbs Rig Supervisors:K. Harding/A. Dorr/R. Reinhardt • Security Level: AK Development Daily Drilling Report (No CostsPIF y. CD5-99 xito ConocoPhillips Report Number: 45 b'eCW,2 Rig: DOYON 19 Report Date: 10/10/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99A Development 43.60 45.0 0.00 15,582.0 15,582.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 76.57 -21.62 11/11/2016 Last Casing String SURFACE,2,337.1ftKB Ops and Depth @ Morning Report 24hr Forecast RIH 7 5/8"Casing—3,800' RIH 7 5/8"casing as per tally&land on hanger @ 15,570' Last 24hr Summary BROOH f/2,136'to 1,478'.Circ casing clean.Attempt to POOH(swabbing).Pump OOH f/1,478'to 179°.LID BHA.C/O upper rams to 7 5/8".Test BOPE. R/U to run casing.RIH 7 5/8"casing to 1,325' General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. 31 F,Patchy Fog,Wind NE @ 6 mph,Vis 10 51.0 m Tested BOPE&rig gas alarms . _.. ; Supervisor dS>r . Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer David Lee Drilling Engineer Time Log �r. Time P , Start Time End Time Dur(hr) phase Op CodeActivity Code_,. Trbl Coder Trbt Class Start Depth(ttKB)', End Depth(ftKB) Operation 00:00 03:00 3.00 INTRM2 CASING BKRM T Hole Shale 2,138.0 1,478.0 BROOH f/2,138 w/730 gpm,2400 Conditions psi, 120 rpm 3 k trq.Pumped nut plug sweep to aid in hole cleaning.Hole un-loading large amounts of clay patties. 03:00 03:15 0.25 INTRM2 CASING OWFF T Hole Shale 1,478.0 1,478.0 F/C(static) Conditions 03:15 06:30 3.25 INTRM2 CASING PMPO T Hole Shale 1,478.0 179.0 Attempt to POOH on elevators. Conditions (Swabbing).Pump OOH f/1,478' to 179' 06:30 06:45 0.25 INTRM2 CASING OWFF T Hole Shale 179.0 179.0 F/C(static) Conditions 06:45 08:30 1.75 INTRM2 CASING BHAH T Hole Shale 179.0 0.0 LID BHA#7 as per SLB Conditions 08:30 08:45 0.25 INTRM2 CASING BHAH T Hole Shale 0.0 0.0 Clean&clear floor Conditions 08:45 09:00 0.25 INTRM2 CASING WWWH T Hole Shale 0.0 0.0 R/U srack washer&wash stack Conditions w/10 bpm @ 130 psi. 09:00 10:30 1.50 INTRM2 CASING BOPE P 0.0 0.0 PJSM,Drain stack.Pull wear ring.C/O upper rams from 3%"x 6"VBR to 7-5/8"solid body. 10:30 11:30 1.00 INTRM2 WHDBOP RURD P 0.0 0.0 R/U to test BOPE.Fill lines with H2O Latest BOP Test Data Date I , i Com 10/10/2016 I ROPE Test'Test with 5"&7 5/8"test joint Test Annular to 250/2 500 psi for 5 min Test choke valves#1 -14 and needle valve to 2 Page 1/3 Report Printed: 9/2512017 • Security Level: AK Development } Daily Drilling Report(No Costs CD5-99 Conocal'hillips Report Number: 45 Rig: DOYON 19 Report Date: 10/10/2016 Time Log Time P Start lime End Time Our(hr) Phase Op Code - Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE) Operation 11:30 16:30 5.00 INTRM2 WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 5"&7 5/8" test joint,Test Annular to 250/2,500 psi for 5 min,Test choke valves#1 -14 and needle valve to 250/3,500 psi for 5 min. HCR Choke and Kill,4"Demco, 5"FOSV,dart&needle valves, auto&manual IBOP,HCR choke &kill,7 5/8"casing rams,3 1/2" X 6"lower VBR's,&blind rams to 250/3500 psi for 5 min.Koomey test;IP=3,000 psi,press after close=1,600 psi,200 psi recovery 26 sec,full recovery 129 sec,N2-4 bottle average=2075 psi.Tested gas alarms.Draw down on man&super choke to 1,100 psi.-Test waived by Jeff Jones of the AOGCC. 16:30 17:15 0.75 INTRM2 WHDBOP RURD P 0.0 0.0 R/D testing equipment.B/D choke&kill lines.Set 10.25"ID wear ring. 17:15 18:45 1.50 INTRM2 CASING RURD P 0.0 0.0 R/U to run casing.R/U Volant, bale extensions,7 5/8"elevators &spiders. 18:45 00:00 5.25 INTRM2 CASING PUTB P 0.0 1,325.0 PJSM.Make up shoe track&RIH w/7 5/8",29.7#,L-80,BTC-M casing as per tally to 1,325'(31 joints in the hole)Check floats on jt#5(good) Mud Check Data . YP Calm Gel(los): .,Get(1Dm) Gel(30m) - "'. HTHP Filtrate Density Temp Solids,Corr. (lb/9a!) 9) ;Type, ',� Depth(ftKB} DensVis(s/qt)t Pu Cala(oP) (Ibf/100ft') (Ibf/100fl') (Ibf/100fte) j (Ibf/iDOfN) MET(16/bbl) (rriLl30miri) '' pH !" • ('F) ',(%) Low Solids 15,582.0 11.00 49 14.0 26.0 11.0 12.0 15.006 22.0 7.2 9.4 88.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 43 13.0 29.0 11.0 13.0 15.006 21.5 7.0 9.4 100.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 43 13.0 29.0 11.0 13.0 15.006 21.5 7.0 9.4 104.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 44 14.0 28.0 11.0 12.0 15.006 22.0 7.1 9.5 118.0 14.5 Non- Dispersed Drill Strings: BHA No.7, -:Steerable / Bit Run No. 5 9 7/8in MD1516,JH7453 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(ins) Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 2,400.0 15,582.0 1.03 16/16/16/16/18 1-1-WT-A-X-I-NO-TD 318 Drill String Components Jts. % • Item Des OD(in) ID(in) .Top Conn Sz(in) .--Top Thread.,= •• Cum Len(ft) 6 3/4"PowerDrive 7 2.810 5 1/2 FH 29.56 6 3/4"Periscope 7.22 2.810 5 1/2 FH 50.91 6 3/4"Telescope 6.9 3.880 4 1/2 IF 79.33 9 3/4"NM Stab 6.84 2.813 4 1/2 IF 86.42 Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report (No Costs CD5-99 ConocoPhfillips Report Number: 45 Rig: DOYON 19 Report Date: 10/10/2016 Drill String Components Jts Item Des , _. 1t,,,, ,, ` ,li V. .:Top Conn Sz(in) Top Thread ! i:., Cunt Len,(Its,,;. Steel Float Sub(NPFV) 6.8' 2.875 4 1/2 IF 88.64 7"Pony DC 7 1/4 2.830 4 1/2 IF 98.73 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 110.61 1 7"NMDC Corrosion ring 6.8 2.880 4 1/2 IF 140.68 NM Stabilizer 6.85 2.875 4 1/2 IF 146.62 1 7"NMDC 6.8 2.880 4 1/2 IF 176.34 Saver Sub 6.9 2.880 4 1/2 FH 179.88 12 HWDP 5 3.000 41/2 IF 547.75 Drilling Jars-Hydraulic 6.15 2.250 4 1/2 IF 578.23 8 HWDP 5 3.000 41/2 IF 821.96 472 Drill Pipe 5 4.276 4 1/2 DS 50 15,582.00 Drilling Parameters t Flow Rate ;A: .End Depth, ,,, S I " (9Finl a ,,liPM 3_ PU Wt t l Strwt SOStrwt �....? ' Mark(ftKB i, ) Cum,Depth(ft) Cum Time(hr}, 1"une(hr)• (OPM) , a—a`i'" tiprn). •SPP( %7 000lbf) M Ibt).... .:tt000lbt} Off Den Tq . DMTp 15,582.0 15,582.0 13,182.00 71.85 Wellbores ' , , ': ' ,••gip/�.' r ., , Wellbore Name Wellbore API/UWI CD5-99A 501032074801 Section Des' Size(in) Act Top(ftK3) Act Stm(ftKB) Start Date!, 4, End Date' CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM2 11 2,347.0 15,582.0 10/1/2016 10/16/2016 PROD1 6 3/4 15,582.0 27,128.0 10/16/2016 11/2/2016 Page 3/3 Report Printed: 9/25/2017 Aft Security Level: AK Development Daily Drilling Report (No Costs) a CD5-99 CotocoPhtl)➢ps3 Report Number: 46 Rig: DOYON 19 Report Date: 10/11/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99A Development 44.60 46.0 0.00 15,582.0 15,582.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 76.57 -21.62 11/11/2016 Last Casing String SURFACE,2,337.1ftKB Ops and Depth @ Morning Report 24hr Forecast RIH with 7-5/8"casing @ 12,500'MD Continue running 7-5/8"casing per tally,C&C above HRZ @ 13,808' MD.Run casing and land hanger @ 15,570'MD.Condition and cement per program. Last 24hr Summary RIH 7 5/8"casing as per tally from 1,325'MD to 10,975'MD.Stop and C&C mud at 6,699'MD and 10,975'MD. General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. 30 F,Cloudy/breeze,Wind E @ 23 mph,Vis 51.0 p_ 10 m ,.: Supervisor Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Joseph Engel Rig Engineer David Lee Drilling Engineer Time Log Time Start Time End Time Our(hr) Phase-• Op Code Activity Code T-X Trbl Code Trbl Class Start Depth(ftKB)'; -End Depth(ftKB) Operation 00:00 10:00 10.00 INTRM2 CASING PUTB P 1,325.0 6,699.0 Continue picking up and running 7-5/8"29.7#L-80 BTCM casing per running order from 1,325'MD to 6,699'MD.P/U=180k, S/0=140k. 10:00 11:45 1.75 INTRM2 CASING CIRC P 6,699.0 6,699.0 Establish circulation and stage pumps up from 1 bpm 228 psi,to 8 bpm 320 psi.CBU,heaviest mud 11.2 ppg out, 11.0 ppg in. 11:45 22:15 10.50 INTRM2 CASING PUTB P 6,699.0 10,975.0 Continue picking up and running 7-5/8"29.7#L-80 BTCM casing per running order from 6,699'MD to 10,975'MD,joint#273. P/U=255k,5/0=155k. 22:15 00:00 1.75 INTRM2 CASING CIRC P 10,975.0 10,975.0 Establish circulation to CBU @ 10,975'MD,above the Albian 96. Stage up from 1 bpm to 5 bpm 480 psi,pumped'A bottoms up @ 00:00 hrs.Heaviest mud out 11.5 ppg, 11.0 ppg in. Mud'Check Data , YP Calc " Gel(105) Gel(10m) ;Gel(30m). -. HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftK&) ,Dens(ib/gal) Vis,(s)gt) PV Cale(eP) !(Ibf/100fP)°° .:(Ibf/100fty)' r'(Ibf/100ft9 i(Ibi/100fY) MET(Ra/bbl) ".(mU30min). pH .,'(F) (%) Low Solids 15,582.0 11.00 62 13.0 29.0 10.0 13.0 15.006 22.0 6.9 9.5 76.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 61 14.0 27.0 10.0 14.0 16.007 21.5 7.0 9.4 81.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 62 14.0 27.0 10.0 14.0 16.007 21.5 7.0 9.4 75.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 50 14.0 27.0 11.0 13.0 15.006 22.0 7.2 9.5 86.0 14.5 Non- Dispersed Latest BOP Test Data 10/10/2016 Date BOPF Test Test with 5'&7 5/8"test joint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and aom... needle valve to 2 Page 112 Report Printed: 9/25/2017 Security Level: AK Development i Daily Drilling Report (No Costs) CD5-99 ConocoPhillips ipskzza Report Number: 46 Rig: DOYON 19 Report Date: 10/11/2016 Injection Fluid .4.Baia •46'.Iiiiii;.A,r. F&uid ..a. 4i:, Source c ;From t.ease;(bblj:: .,. pest Vendor. ...'. <-Manifest Number ' Note :.:, Water Based Mud CD5-99 250.0 CD1-01 AES 477164 CD5-99 Source Well Water Based Mud CD5-99 250.0 CD1-01 AES 477166 CD5-99 Source Well ; • . . , Wellbore5 4�"t''�t.,rti .�-',- ' 3 E__ iiblrl .11 .«x r Wellbore Name Wellbore API/UWI CD5-99A 501032074801 Section Des Size(kt) ,,', .„,'N •ActToptTtKB} ActStni(ftKS) Start Date =. End Bate tA.': CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM2 11 2,347.0 15,582.0 10/1/2016 10/16/2016 PROD1 6 3/4 15,582.0 27,128.0 10/16/2016 11/2/2016 • Page 2/2 Report Printed: 9/25/2017 Security Level: AK Development • Daily Drilling Report (No Costs 4,::,..51e4 Wens CD5-99 PIN ConocoPFtijirPS Report Number: 47 Rig: DOYON 19 Report Date: 10/12/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99A Development 45.60 47.0 0.00 15,582.0 15,582.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 76.57 -21.62 11/11/2016 Last Casing String SURFACE,2,337.1ftKB Ops and Depth @ Morning Report 24hr Forecast Circulate and condition for cement job,casing landed @ 01:15 Continue running casing and land hanger @ 15,570'MD.Condition and cement(2 stage)per program.Set and test packoff.Lay down 5"DP Last 24hr Summary Continue running 7-5/8"casing per tally,C&C above HRZ @ 13,808'MD.Run casing to 15,392'MD. General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. 30 F,Cloudy/breeze,Wind E @ 21,WC17,Vis 51.0 10 m Supervisor Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Joseph Engel Rig Engineer David Lee Drilling Engineer Time Log i 1 r3i,is t�- Time Start Time End Time Dur(hr) Phase' "Op Code Activity Code-r T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:15 1.25 INTRM2 CASING CIRC P 10,975.0 10,975.0 Continue to CBU @ 10,975'MD, above the Albian 96.Stage up from 5 to 7 bpm 520-480 psi. Heaviest mud out 11.5 ppg, 11.0 ppg in. 01:15 10:15 9.00 INTRM2 CASING PUTB P 10,975.0 13,808.0 Continue picking up and running 7-5/8"29.7#L-80 BTCM,XO to H563 casing per running order from 10,975'MD to 13,808'MD, joint#343.P/U=315k,S/0=160k. (Had 50k bobble @ 13,668'MD, sticky out of slips after connection) 10:15 12:00 1.75 INTRM2 CASING CIRC P 13,808.0 13,808.0 Circulate and condition @ 13,808'MD,above the HRZ. Stage up from.5 to 5.5 bpm 510- 640 psi.P/U=315k,5/0=160k, 420k to break over. 12:00 14:45 2.75 INTRM2 CASING CIRC P 13,808.0 13,808.0 Continue to circulate and condition @ 13,808'MD,above the HRZ.Stage up from 5.5 to 8 bpm 460 psi.Heaviest mud out 11.7+ppg briefly then dropped off to 11.0+.P/U=315k, S/0=160k with pumps on. 14:45 00:00 9.25 INTRM2 CASING PUTB P 13,808.0 15,392.0 Continue picking up and running 7-5/8"29.7#L-80 H563 casing per running order from 13,808' MD to 15,392'MD.5/0=105k. Started taking weight at 14,465' MD,to block weight(60k)at times.Continued RIH slowly, improved at—15,100'MD to S/0 of—105k. Latest BOP Test Data 10/10/2016 BOPF Test•Test with 5"&7 5/8"test joint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and needle valve to 2 Page 1/2 Report Printed: 9/25/2017 IDSecurity Level: AK Development Daily Drilling Report (No Costs) u x CD5-99 Report Number: 47 ConocoPhlilips ".Avk.. Rig: DOYON 19 Report Date: 10/12/2016 Mud Check Data YP Calms Ge4(10s) Gel(10m) Gel(30m) -HTNP Filtrate 4., Density Temp Solids Dom; Type Depth(ft KB). Dens'.(lb/gal) Via(s/qt) PV Cale(cP) '. (Ibf/100ft)' - (tbf/100(f). (lbf/100ft) (Ibf/100ft2y: .h1BT ab/bbl)° (mLf30min) pH ('F) (%) Low Solids 15,582.0 11.00 53 14.0 27.0 10.0 13.0 15.006 22.5 6.9 9.0 80.0 15.0 Non- Dispersed Low Solids 15,582.0 11.00 47 14.0 29.0 10.0 12.0 13.005 22.5 6.8 9.1 73.0 15.0 Non- Dispersed Low Solids 15,582.0 11.00 45 12.0 26.0 9.0 11.0 13.005 22.5 6.8 9.2 74.0 15.0 Non- Dispersed Low Solids 15,582.0 11.00 45 14.0 25.0 10.0 13.0 15.006 23.0 6.9 9.4 76.0 15.0 Non- Dispersed 1Neilbores Wellbore Name Wellbore API/UWI CD5-99A 501032074801 SectionI• Des- ; .• Size(in) :. Act Top(ftKB) - Act Btm(ftKB) ri. - Start Date End Date CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM2 11 2,347.0 15,582.0 10/1/2016 10/16/2016 PROD1 6 3/4 15,582.0 27,128.0 10/16/2016 11/2/2016 Page 2/2 Report Printed: 9/25/2017 Security Level: AK Development • Daily Drilling Report (No Costs) CD5-99 ConocoPhillips Report Number 48 Rig: DOYON 19 Report Date: 10/13/2016 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-99A Development 46.60 48.0 0.00 15,582.0 15,582.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/27/2016 8/28/2016 54.95 76.57 -21.62 11/11/2016 Last Casing String INTERMEDIATE,15,570.6ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5"DP,flush and FP annulus on CD5-99 Continue laying down all 5"DP.Perform annular LOT and flush/FP on CD5-99A annulus.C/O saver sub,cut/.slip.Test BOPE with 4" and 4W test joints.M/U 6%"BHA and RIH P/U 4"DP. Last 24hr Summary Continue running casing and land hanger @ 15,570'MD.Condition and cement(2 stage)per program.Set and test packoff.Lay down 5"DP.Change out 7-5/8" rams to 3W x 6"VBR. General Remarks Weather Head Count No AIS.Camp and Rig on Hi line power. Overcast,27°F,Wind E 21 mph,WC 13,Vis 8 51.0 mi Supervisor x � Yr ' �', Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Joseph Engel Rig Engineer David Lee Drilling Engineer Time Log '6M . ,PAP,v.041Ad3 .6.s ,. fie, _ Start Time End,Time Dur(hr) Phase Op Code- Activity Code -T-X Trbl Code Trial Class Start Depth(EKE) End Depth(ftKB) Operation ' 00:00 01:15 1.25 INTRM2 CASING PUTB P 15,392.0 15,570.0 Continue RIH with 7-5/8"Hyd563 29.7#L-80 casing from 15,392', M/U hanger and landing joint, land on hanger @ 15,570.58' MD.Calc Disp=177.56 bbl, Actual Disp=124 bbl.S/0=130k, P/U=N/A. SIMOPS verify pipe count and empty pipe shed. 01:15 01:45 0.50 INTRM2 CEMENT CIRC P 15,570.0 15,570.0 Establish circulation @.5 bpm, 510 psi. SIMOPS-Load pipe shed with 4" DP. 01:45 02:15 0.50 INTRM2 CEMENT HOSO P 15,570.0 15,570.0 Shut down pumps,drain stack to verify hanger is landed,good per FMC. 02:15 07:15 5.00 INTRM2 CEMENT CIRC P 15,570.0 15,570.0 Circulate and condition mud for cement,.5 bpm to 8 bpm,480- 535 psi.Attempt to reciprocate pipe,P/U from 450k-490k max, no go. 07:15 07:30 0.25 INTRM2 CEMENT RURD P 15,570.0 15,570.0 Shut down pumps,blow down top drive.R/U cement lines. 07:30 09:00 1.50 INTRM2 CEMENT CIRC P 15,570.0 15,570.0 Continue circulate and condition @ 8 bpm,830 psi. SIMOPS-PJSM on cement job. 09:00 12:00 3.00 INTRM2 CEMENT CMNT P 15,570.0 15,570.0 Flood lines with water,test lines to 3800 psi.SLB pumped 41 bbl of 12.5 ppg Mud Push II.Drop bottom plug.SLB pumped 154.5 bbl of 15.8 ppg cement.Drop top plug.SLB kick out with 20 bbl water,rig displaced with 6892 strokes to bump plug(694 bbl). CIP @ 11:50 hrs,no losses. Latest BOP Test Data Date I a 10/10/2016 ROPE Test.Test with 5"&7 5/8"test ioint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and needle valve to 7 Page 1/3 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs CD5-99 Conor-oPhillips Report Number: 48 Rig: DOYON 19 Report Date: 10/13/2016 Time Log - Start Time End Time Our(hr) Phase Op Code ' Activity Code 'T-r XP' TrbI Code Trbl Class: Start Depth(ftKB) End Depth MINT) -, - Operation • 12:00 13:15 1.25 INTRM2 CEMENT CIRC P 15,570.0 15,570.0 Open stage collar with 3150 psi, establish circulation to 8 bpm, 520-530 psi. SIMOPS-PJSM on 2nd stage cement. 13:15 15:00 1.75 INTRM2 CEMENT CMNT P 15,570.0 15,570.0 Peform 2nd stage cement job. Flood cement lines,pressure test to 3000 psi.SLB pumped 42 bbl 12.5 ppg MudPush II,65 bbl 15.8 ppg cement.Drop closing plug. SLB kick out with 20.2 bbl water, rig displaced with 2867 stks(288 bbl).Bumped plug and pressure up to 1900 psi,held 5 minutes. Bleed pressure and check floats- good.CIP @ 14:34 hrs. 15:00 15:45 ' 0.75 INTRM2 CEMENT RURD P 15,570.0 0.0 Blow down cement line,rig down and lay down Volant CRT,lay down landing joint. 15:45 16:15 0.50 INTRM2 CEMENT RURD P 0.0 0.0 Pick up test joint and M/U retrieval tool.Pull wear ring. 16:15 17:15 1.00 INTRM2 CEMENT WWSP P 0.0 0.0 Set and test 7-5/8"packoff to 5000 psi for 10 minutes witnessed by CPAI rep,good. 17:15 17:30 0.25 INTRM2 CEMENT RURD P 0.0 0.0 Lay down test joint,install 5" elevators.Grease iron roughneck and draw works. 17:30 00:00 6.50 INTRM2 CEMENT PULD P 0.0 0.0 Lay down 5"DP from derrick via mouse hole. SIMOPS-Replace mud lines in pits,C/O upper rams from 7-5/8" to 3'A'x 6"VBR. Mud Check Data YP Calc ,Gel(10$) Gel(1Om) Gel(30m) HTHP Filtrate • Density Temp Solids,Coir. • Type Depth(f5KB) Dens(lb/gal) Vis(s/qt) PV Calc(CP) (Ibf/100ft') •• (lbf/100ft') (lbf/1005') (Ibf/100ft3) MET(Ib/bbl) (mt13Omin) 1 pH . . ('F) (%) Low Solids 15,582.0 11.00 44 14.0 22.0 9.0 10.0 13.005 22.0 6.9 9.5 73.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 44 13.0 23.0 9.0 10.0 14.006 22.0 6.8 9.5 74.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 43 14.0 21.0 9.0 10.0 13.005 22.0 6.6 9.6 75.0 14.5 Non- Dispersed Low Solids 15,582.0 11.00 46 14.0 22.0 9.0 11.0 14.006 22.5 6.8 9.6 73.0 14.5 Non- Dispersed Injection Fluid Fluid '- Source - From Lease(bbl) Dest Vendor Manifest Number Note. , Water Based Mud CD5-99 265.0 CD1-01 AES 477167 CD5-99 Source Well Water Based Mud CD5-99 265.0 CD1-01 AES 477168 CD5-99 Source Well Water Based Mud CD5-99 265.0 CD1-01 AES 477169 CD5-99 Source Well Water Based Mud CD5-99 250.0 CD1-01 AES 477170 CD5-99 Source Well Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report (No Costs CD5-99 iti pis Report Number: 48 ConactaFtlRig: DOYON 19 Report Date: 10/13/2016 Weilbores s -,,,t,,,,,,,., h . Wellbore Name Wellbore API/UWI CD5-99A 501032074801 section Des -: !RI= , ,'�///�/ ,,,,orki{tss,6 a c,'v ?.; Act Top(ftKB) Act.Btns(ftKB) :110p,stOrtbate 1,R,,,,r'':-.,,V End Date )) CONDI 24 36.6 115.0 4/14/2016 4/14/2016 SURFAC 131/2 115.0 2,347.0 8/28/2016 9/1/2016 INTRM2 11 2,347.0 15,582.0 10/1/2016 10/16/2016 PROD1 6 3/4 15,582.0 27,128.0 10/16/2016 11/2/2016 Casing Strt f . ... ' ,...... ,.: Csg Run Date' OD(in) Wt/Len(lb/ft) fade Del �K6) a N_ ;._ `i�,i . INTERMEDIATE 10/13/2016 7 5/8 29.70 L-80 15,570.6 Cement ",, ... Intermediate Casing Cement -Started @ 10/13/2016 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-99A INTERMEDIATE, 15,570.6ftKB Sonic and SCMT Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 13,854.0 15,570.6 8 580.0 ry'? m FiWd. Class Amount(sacks} Vol Pumped(bbl) Dens(Ib/gal) Yield(ft./sack) 'Est Top{ftKB) Eat Dim(AKE) Intermediate Cement G 734 154.5 15.80 1.16 13,854.0 15,570.6 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Casing Cement 5,958.0 6,708.0 8 360.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(Ib/gal) Yield(n tsack) Est Top(ftKB) Eat Dim(fED) Intermediate Cement G 311 41.9 15.80 1.16 5,958.0 6,708.0 Page 3/3 Report Printed: 9/25/2017 -- "-1 -r0 C) V' CD r. 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Ttic A L O 4/ 00 0000 000 O 0000000000 O X as I - ++ Cl) c O N U) 0 U) 0 Lx) 0 U) O U) O Lx) O L° O U) O U) O U) 0• > d es .1", a) m o0or- r ticiri rive Vi 666r- h: 6 66ca CO / i. dcn a t c 0000 0000 o (0U) U) 0000 Lx) 0000 0 NU) Nr. 0 N- . CO 4c) CD M OU) 0U) CCcrC) 4 C) CA co 1- 0) t% Cement Detail Report 4• CD5-99 ConocoPhilhps String: Intermediate Casing Cement Job: DRILLING ORIGINAL,8/27/2016 00:00 Cement Details :.: " ...� � .... ; WAWA- Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/13/2016 09:00 10/13/2016 15:00 CD5-99A Comment Cemented with full returns Cement Stages Stage#1 U. Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 13,854.0 15,570.6 Yes Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 8 7 580.0 670.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Flood lines with water,test lines to 3800 psi.SLB pumped 41 bbl of 12.5 ppg Mud Push II.Drop bottom plug.SLB pumped 154.5 bbl of 15.8 ppg cement.Drop top plug.SLB kick out with 20 bbl water,rig displaced with 6892 strokes to bump plug(694 bbl).CIP @ 11:50 hrs,no losses. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 15.8 ppg Class G 13,854.0 15,570.6 734 G 154.5 intermediate cement Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 0.00 15.80 128.0 0.00 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 5,958.0 6,708.0 Yes Yes No Cement Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 8 7 360.0 760.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,707.0 PDC bit 6,711.5 6 3/4 Comment Peform 2nd stage cement job. Flood cement lines,pressure test to 3000 psi.SLB pumped 42 bbl 12.5 ppg MudPush II,65 bbl 15.8 ppg cement. Drop closing plug.SLB kick out with 20.2 bbl water, rig displaced with 2867 stks(288 bbl). Bumped plug and pressure up to 1900 psi,held 5 minutes. Bleed pressure and check floats-good.CIP @ 14:34 hrs. Cement Fluids 8,Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 15.8 ppg Class G 5,958.0 6,708.0 311 G 41.9 intermediate cement Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 0.00 15.80 162.0 0.00 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 9/25/2017 • • Additional information regarding CD5-17 • CD5-17, 10-3/4", Surface Casing Well: CD5-17 10-3/4"s 45.5#, L-80, Hyd 563 DPLS Casing Date: 4/27/2017 * onocoPhillips no I Rig: Doyon 19 Alaska,Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of.String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 36.62 FMC 10-3/4" Casing Hanger .18 36.62 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt, Pin X Pin 2.26 36.80 Jts 5 to 53 49 Jts 10-3/4", 45.5#, L-80, HYD563 DPLS Casing 2001.29 39.06 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt (Doped) 19.81 2040.35 Jts 4 to 4 1 Jts 10-3/4", 45.5#, L-80, BTC Pin X HYD563 Box Casing XO Jt 42.76 2060.16 Jts 3 to 3 1 Jts 10-3/4", 45.5#, L-80, BTCM Casing 37.71 2102.92 10-3/4" HES Float Collar 1.21 2140.63 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTCM Casing 78.01 2141.84 10-3/4" HES Composite Shoe 2.69 2219.85 2222.54 2222.54 2222.54 2222.54 10-3/4" Shoe at 2,222.54' MD/2,181' TVD 2222.54 13-1/2" TD at 2,232' MD /2,190' TVD, 10' rathole 2222.54 2222.54 2222.54 BakerLok up to pin of Jt#4 2222.54 2222.54 2222.54 1 Centek 10' up from shoe w/stop rings on Jt#1 2222.54 1 Topco Bow Spring 30' up from pin w/stop rings on Jt#2 2222.54 1 Centek 20' up from pin w/stop rings on Jt#3 2222.54 1 Topco Bowspring centralizer every joint from #3 to#12 2222.54 1 Centek centralizer every joint from#13 to#52 Floating 2222.54 2222.54 2222.54 2222.54 2222.54 Total Centralizers 2222.54 (40) Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2222.54 (10) Top-Co PN 300-273-434 10.75"x 17.09" bowsprings 2222.54 2222.54 2222.54 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 153 K MU Tq with Volant-trq for Hyd 563 dpls 19.4K ft/lbs, Hyd 563 doped 16.2 ft/lbs Down Wt 145 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:K. Harding/R.Reinhardt Security Level: AK Development410 Daily Drilling Report(No Costs) CD5-17 Conoc ''hillips Report Number: 5 lmk.. Rig: DOYON 19 Report Date: 4/27/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-17 Development 3.10 5.0 87.00 2,145.0 2,232.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/23/2017 4/25/2017 42.06 40.16 1.90 6/2/2017 Last Casing String CONDUCTOR,114.0ftKB Ops and Depth @ Morning Report 24hr Forecast Cementing surface casing Cement 10-3/4"casing shut in WOC.R/D annular and riser,N/U well head and BOPE. Last 24hr Summary Drill to TD 2,232'MD,2,190'TVD.C&C,POOH,L/D BHA#1.R/U and run 10-3/4"casing to 2,183', P/U hanger and landing jt,land hanger @ 2,222'MD. Establish circulation,stage pumps up to 2 bpm. General Remarks Weather Head Count No AIS,Rig and Camp on Hi Line power @ CD5.Daily cost includes NES rig move charges. Overcast,4°F,Wind E 14 mph,WC-14,Vis 10 52.0 mi Supervisor Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Tom Polasek Rig Engineer Kurt Alexa Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code' Activity Code. <-T. Trbl Code Trbl Class' Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:15 1.25 SURFAC DRILL DDRL P 2,145.0 2,232.0 Directional drill from 2,145'MD to 2,232'MD,2,190'TVD.ADT 1.25,ART=.23,AST=1.02. P/U=130k,S/0=125k, ROT=120k,WOB=20-30k,Tq on/off=5/2k @ 80 rpm.775 gpm @ 2300 psi.Weight up to 10.0 ppg on the fly. 01:15 02:15 1.00 SURFAC CASING CIRC P 2,232.0 2,047.0 Circulate 2 bottoms up,pump around 34 bbl Nut Plug sweep @ 775 gpm,2220 psi,80 rpm,2k Tq.Rack back stand after each BU. 02:15 03:00 0.75 SURFAC CASING OWFF P 2,047.0 2,047.0 Monitor well for flow,static for 30 minutes.Blow down top drive. 03:00 04:00 1.00 SURFAC CASING TRIP P 2,047.0 1,674.0 POOH on elevators from 2,047' MD to 1,674'MD observe improper displacement, Calculated 3.2 bbl,Actual 1 bbl. Pull 35k over @ 1,913', 1,881', 1,806'MD,able to work through OK. 04:00 04:15 0.25 SURFAC CASING CIRC P 1,674.0 1,580.0 Circulate bottoms up @ 750 gpm, 1990 psi,80 rpm,2k Tq.Observe shakers unloading clay. 04:15 04:45 0.50 SURFAC CASING PMPO P 1,580.0 1,297.0 Pump out of hole from 1,580'MD to 1,297'MD @ 500 gpm,970 psi. 04:45 07:15 2.50 SURFAC CASING PMPO P 1,297.0 185.0 Continue pumping out of hole from 1,297'MD to 185'MD @ 300 gpm 420 psi(reduced rate in permafrost).Hole unloaded clay @ 563'MD. 07:15 07:30 0.25 SURFAC CASING TRIP P 185.0 94.0 POOH on trip tank from 185'MD to 94'MD. Latest BOP Test Data Page 1/3 Report Printed: 9/25/2017 Security Level: AK Development dawn DailyDrillingReport (No Costs) p CD5-17 CoriocoPh ;;i;ps Report Number: 5 Rig: DOYON 19 Report Date: 4/27/2017 Time Log Time P Start Time End Tarte Dur(hr) Phase Op Code -'' Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftK8) Operation 07:30 08:30 1.00 SURFAC CASING BHAH P 94.0 0.0 PJSM,UD BHA#1 from 94'per DD/MWD.Calc fill=31.91 bbl, Actual fill=53 bbl. 08:30 09:15 0.75 SURFAC CASING BHAH P 0.0 0.0 Clean and clear rig floor of BHA components. SIMOPS-Prepare pumps for casing run,install air boot on pollution pan. 09:15 10:45 1.50 SURFAC CASING RURD P 0.0 0.0 R/U to run 10-3/4"casing,R/U Volant CRT,bail extensions, elevators,350T spiders.Monitor well on TT, 1 bbl lost. 10:45 12:00 1.25 SURFAC CASING PUTB P 0.0 182.0 PJSM,P/U and RIH with 10-3/4" casing per detail to 182'MD.P/U shoe,2 jts and float collar, Establish circulation and check floats-Good. 12:00 20:15 8.25 SURFAC CASING PUTB P 182.0 1,487.0 Continue P/U and RIH with 10- 3/4"45.5#L-80 Hydril 563 casing from 182'MD to 1,497'MD.Tight @ 388'MD,wash down @ 3 bpm 30-150 psi from 388'to 837'MD. Ran 11 total bow springs,switch to Centek centrilizers due large OD and rigidity of bow springs. 20:15 21:15 1.00 SURFAC CASING CIRC P 1,487.0 1,487.0 Circulate bottoms up below permafrost,stage pumps up to 6 bpm,160 psi.P/U=125k, 5/0=112k.Pumped 120 bbl total. 21:15 22:45 1.50 SURFAC CASING PUTB P 1,487.0 2,183.0 Continue P/U and RIH with 10- 3/4"45.5#L-80 Hydril 563 casing from 1,487'MD to 2,183'MD. 22:45 23:00 0.25 SURFAC CASING CIRC P 2,183.0 2,183.0 Establish circulation,stage up to 2.5 bpm, 180 psi,P/U=135k, 5/0=110k. 23:00 23:30 0.50 SURFAC CASING PUTB P 2,183.0 2,183.0 Make up hanger and split landing joint. 23:30 23:45 0.25 SURFAC CASING HOSO P 2,183.0 2,222.0 Land hanger,casing on depth @ 2,222'MD 23:45 00:00 0.25 SURFAC CEMENT CIRC P 2,222.0 2,222.0 Establish circulation stage pumps up to 2 bpm, 170 psi.P/U=135k, S/0=110k. Drill Strings;; BHA No.1 - Surface /Bit Run No. 1.- 13 1/21n„VM-3,5260379 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 114.0 2,232.0 0.7615/16/16/16 2-4-WT-A-E-2-RG-TD 30 Drill String Components Jts Item,Des • OD(in) ID(in) Top Conn Sz(in) ! Top Thread Cum Len(ft) 8-1/4"PDM 1.5°bend 8 1/4 2.125 6 5/8 Reg 32.74 12 1/8"NM Stabilizer,Ported float 8.35 2.880 6 5/8 Reg 40.33 1 8"Pony Drill Collar 8.38 2.875 6 5/8 Reg 50.02 1 8"Pony Drill Collar 8 2.813 6 5/8 Reg 60.08 1 8 1/4"MWD 8.4 5.109 6 5/8 Reg 87.11 8 1/4"NM UBHO 8.1 2.875 6 5/8 Reg 90.70 8 1/4"NM XO 8 2.810 4 1/2 IF 94.11 1 6 7/8"NMDC 6.85 2.875 4 1/2 IF 124.52 Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report (No Costs j, CD5-17 loPlliMlpss Report Number: 5 Rig: DOYON 19 Report Date: 4/27/2017 Drill String Components .Its ' •..; NgeeitDes4A05 - . .... OP.,Cia ID(in) Tap Corot Sz(in) / a'op'Thhread Cu n Leto fit). • 1 6 7/8'NMDC 6.7 2.875 4 1/2 IF 154.53 7"Saver Sub 7 2.880 4 1/2 IF 157.71 13 5"HWDP x13 5 3.000 4 1/2 IF 556.35 1 Drilling Jars-Hydraulic 6 1/4 2.250 4 1/2 IF 586.15 8 5"HWDP x 8 5 3.000 4 1/2 IF 830.35 42 Drill Pipe 5 4.276 4 1/2 IF 2,232.00 Drilling Parameters ,.64444,,,:. e.m,. 3 , ,�� Flow Rate End Dgptlt Sliding (9Pm) Vi/OB RPM PU SlrWt Dritl 81t Wt. SO Str Wt Start(11Ka) (ftKB) Gum Depth(ft) Gum Drill Time(hr( Time(ht)' (gpm) (10001bf)', (rpm) SPP(pal) (10001F t) r,.(l000ibf) (10001bf( Off Btm Tq Drill Tq 2,145.0 2,232.0 2,118.00 16.68 1.02 750 30 80 2,300.0 130 120 125 2.0 5.0 2,232.0 2,232.0 ' rir"G YYejibores ;.;. ..:. C o, 3'1111 .. y�% j431j '1 1...... 1 4; 1 ','':00,111014",:-",";-- . ...... Wellbore Name Wellbore API/UWI CD5-17 501032075400 Sectiafl;De's A04 Size( ) 3iidi: ActTop(ftKB) Act Elm(IES). .,, Sted.Dete`' ? sq- End Date, CONDI 20 36.6 114.0 4/4/2017 4/4/2017 SURFAC 131/2 114.0 2,232.0 4/25/2017 4/29/2017 INTRM1 101/2 2,232.0 15,831.0 4/29/2017 5/15/2017 PROD1 6 3/4 15,831.0 28,645.0 5/15/2017 6/11/2017 Survey Data -€ . ..: 1 .. .:i. MD(ftK8) ' ,.tnat('}:[. Azm(°) TVD 8) VS fit) NS( %O�O/O 1 ,.//F ' (ft}" OLE('1106ft) 2,158.50 22.62 131.70 2,122.47 223.41 -130.67 230.14 2.89 Page 3/3 Report Printed: 9/25/2017 lb Security Level: AK Development :th Daily Drilling Report (No Costs CD5-17 Report Number: 6 E Rig: DOYON 19 Report Date: 4/28/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-17 Development 4.10 6.0 0.00 2,232.0 2,232.0 Actual Start Date Original Spud Date AFE Our Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/23/2017 4/25/2017 42.06 41.16 0.90 6/3/2017 Last Casing String SURFACE,2,222.5ftKB Ops and Depth Morning Report 24hr Forecast Testing BOPE w/5"TJ to 250/3500 psi,2500 psi annular. N/U BOPE and MPDE.Test BOP w/5"test joint,AOGCC waived witness.P/U BHA and RIH,test casing,drill out and displace to LSND.FIT to 18.0 ppg,Drill 9-7/8"x 10-1/2"intermediate. Last 24hr Summary Cement 10-3/4"casing,close annular and WOC.P/U 94'of intermediate BHA,service rig,clean pits,prep drillpipe with NCS30 pipe dope for intermediate section drilling.R/D annular and riser,N/U well head and BOPE. General Remarks Weather Head Count No AIS,Rig and Camp on Hi Line power @ CD5.Daily cost includes surface casing and Fair,-5°F,Wind NE 10 mph,WC-22,Vis 10 m 52.0 cement charges. Supervisor - Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Tom Polasek Rig Engineer Kurt Alexa Drilling Engineer Time Log Time P " Start Time End Time Dur(hr) , Phase' Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth"(ftKB) End Depth(MKS) Operation 00:00 01:15 1.25 SURFAC CEMENT CIRC P 2,222.0 2,222.0 Circulate and condition for cement job,stage up to 8 bpm, 200 psi. SIMOPS-UD bail extensions and casing elevators. 01:15 02:15 1.00 SURFAC CEMENT CIRC P 2,222.0 2,222.0 Pump around 31.5 bbl weighted Nut Plug sweep with dye to gauge hole size @ 8 bpm,200 psi.Calculated return @ 3749 stks,Actual return @ 3430 stks. 02:15 02:30 0.25 SURFAC CEMENT RURD P 2,222.0 2,222.0 Rig up 1502 cement hose to swivel.Close auto and manual IBOP. 02:30 03:30 1.00 SURFAC CEMENT CIRC P 2,222.0 2,222.0 Continue circulate and condition ©8 bpm,400 psi through cement lines. SIMOPS-PJSM on cement job. 03:30 06:15 2.75 SURFAC CEMENT CMNT P 2,222.0 2,222.0 SLB pressure test lines to 3100 psi,good.Pump 75.1 bbl 10.5 ppg MudPush II,drop bottom plug.Pump 302 bbl 11 ppg lead cement @ 5.5 bpm 280 psi WHP. Observe Mud Push on shaker @ 285 away.Swap to tail cement, pump 60.2 bbl 15.8 ppg tail @ 4 bpm,340 psi wWHP.Drop top plug and kick out with 10 bbl water.Rig displace @ 8 bpm, 850 psi for 1850 stks,slow to 3 bpm 540 psi to bump,bump plug @ 1935 stks.Pressure up to 1050 psi and hold 5 min.Bleed off pressure and check floats good.CIP @ 06:06 hrs. 110 bbl good 11.0 ppg cement to surface after a clabbered/thick fluids cleared Latest BOP Test Data Page 1/3 Report Printed: 9/25/2017 Security Level: AK Development amigaitir. • Daily Drilling Report (No Costs) 11 CD5-17 04 ConocoPhillips Report Number: 6 Rig: DOYON 19 Report Date: 4/28/2017 Time Log Time P Start Time End Time Our(hr) Phase Op Code Activity Code -T-X Trbl Code. Trhl Class Start Depth(ftKB) End Depth(ftKB) Operation 06:15 07:30 1.25 SURFAC CEMENT RURD P 2,222.0 0.0 Flush riser and 20"annular, function annular 3X flushing with black water©9.5 bpm,close annular on 4th function.Blow down and rig down cement equipment,rig down Volant CRT, lay down split landing joint. 07:30 10:00 2.50 SURFAC CEMENT WOC P 0.0 0.0 Perform derrick inspection,clean and inspect top drive,clean pits. Load pipe shed with 5"DP. 10:00 12:00 2.00 SURFAC CEMENT WOC P 0.0 0.0 Mechanic work on pipe skate, perform MP2 work orders,clean 5"drill pipe box and pin,prepare for NCS30 high friction facter pipe dope application for top 3,000'of intermediate section. 12:00 16:00 4.00 SURFAC CEMENT WOC P 0.0 0.0 Continue cleaning box and pin on 102 jts 5"DP for NCS30 pipe dope application.Cleaning pits, complete work on pipe skate. 16:00 17:00 1.00 SURFAC CEMENT WOC P 0.0 0.0 Break down NM flex collars in derrick,M/U NM stabilizer and 10%"under reaner,stand back in derrick. 17:00 18:30 1.50 SURFAC CEMENT WOC P 0.0 0.0 Continue cleaning pipe connections on 5"DP,cleaning pits. 18:30 19:30 1.00 SURFAC CEMENT OWFF P 0.0 0.0 Verify annular pressure 0 psi, open and monitor for flow,static. Open annular,make up split landing joint and lay down.Lay down mousehole. 19:30 21:00 1.50 SURFAC CEMENT NUND P 0.0 0.0 PJSM,Flush riser and N/D flowline,mud bucket,hole fill lines,UD upper and lower risers. 21:00 22:00 1.00 SURFAC CEMENT NUND P 0.0 0.0 N/D surface annular and starting head. 22:00 23:30 1.50 SURFAC WHDBOP NUND P 0.0 0.0 Prep and N/U wellhead.Test wellhead to hanger neck seals to 1000 psi for 10 minutes,good. 23:30 00:00 0.50 SURFAC WHDBOP NUND P 0.0 0.0 N/U new FMC speedhead adapter to wellhead.Prep stack for N/U. Mud Check Data ''; YP Calc` Gel(10s) Gel(10m) Gel(30m): HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gal) Yrs(s/qt) PV Calc(cP) (lbf/100ft') (Ibf/100fk) (Ibf/100ft) (Ibf/100ft')is MBT(Ib/bbl) (mU30min) pl k (`F)' ' (%) DRILPLEX 2,232.0 10.00 34 13.0 4.0 1.0 5.0 10.004 15.0 0.0 10.8 8.5 DRILPLEX 2,232.0 10.00 34 14.0 3.0 1.0 5.0 11.005 15.0 0.0 10.9 8.5 DRILPLEX 2,232.0 10.00 34 13.0 5.0 1.0 3.0 12.005 15.0 0.0 10.9 8.5 DRILPLEX 2,232.0 10.00 46 16.0 15.0 14.0 25.0 36.015 18.0 0.0 10.8 9.0 Page 2/3 Report Printed: 9/25/2017 0 Security Level: AK Development Daily Drilling Report (No Costs CD5-17 i[C�Ss Report Number: 6 Cora3coPht„ 1,, Report Date: 4/28/2017 Rig: DOYON 19 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Water Based Mud 275.0 CD1-01 AES 483552 CD5-17 Source well Wellbores Wellbore Name Wellbore API/UWI CD5-17 501032075400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 20 36.6 114.0 4/4/2017 4/4/2017 SURFAC 131/2 114.0 2,232.0 4/25/2017 4/29/2017 INTRM1 101/2 2,232.0 15,831.0 4/29/2017 5/15/2017 PROD1 6 3/4 15,831.0 28,645.0 5/15/2017 6/11/2017 Casing Strings Csg Des Run Date CD(in) Wt/Len(Ibtft) Grade Set Depth(ftKB) Corn SURFACE 4/28/2017 10 3/4 45.50 L-80 2,222.5 42 Centek SI110-3/4”x 13-1/2"centralizers, 10 Top- Co 10-3/4"x 17.09"bow springs. Cement Surface Casing Cement -Started @ 4/28/2017 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-17 SURFACE,2,222.5ftKB 110 bbl of 11 ppg lead to surface Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.6 2,232.0 3 540.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(Ib/gal) ; Yield(ft'/sac() Est Top(ftKB) Est Btm(ftKB) Surface Cement G 1,001 302.0 11.00 1.91 36.6 1,732.0 Tail Cement G 290 60.8 15.80 1.16 1,732.0 2,232.0 Page 3/3 Report Printed: 9/25/2017 ► CCC o0_ O o_ _00 Lf) Ln U0 LO Ln o o CD L f) ,.:t. M N r O 0 0 0 0 0 0 0 0 'y O6) CDC) 10) 0) 0 CA O) CA CA o) 6) 6) C) 0) C) CA 0) ) .Y (I) 4'' C Q CU C7— N - E ca.0 U) M I- OL O 0 0 O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 O X 10C n, .?.. (n c O N )VO V) O LU O U) O L f) O LO O U) O U) O LU O V) O _T _ E E CL N 2E OOO NNM M ,r L!•) Ln CO CO f� COoOO) 0 O CO E .- E L d i a - E OOOO OOOO OOO O b O O CO O) CO CO N- r CO Ln (/)a. i 0) (7) N M V Ln Lfl N- Lp CT 3) = C C2 CN/f Q E 0.0a) 7 o "ri D U) OrNM LO Co f- CO 6) O 0 E in Y' U) a) O () L i " _ LC) LU CD CD Oo0 _o 000 0 000 cot NNNN NNr- - 00 O OOO .lCU) d ^ C U) Cfl Cfl Co Lfl Cfl Lfl CO CO CO Lfl Lfl Co CO CO Cfl d C) ) n E m - C2 coMMM M M co co M M M M MMM E fC m -o m OO o y C C NM ,4- V CC CO 0) O LO ONO � 'aM ZD > o w > �M rl E5 O p) r .. E O Ln O Ll) O Ln O O LO Ln LO O O O Lt) O o Ln •O 7 ' U) NON O N O O N N N Ln O Lf) N O LO N - U) 0 CL N N LMLO COOCV V LU COO N Lt) COOMLOCO d 10 C :V C- Q v- '- V- CA N NNP') MMM E CU J EE-__- E U) ONd• CO OOONd' CoCo0 N CoCOC7NM M E Y � - rt- •- � � N N N (NI NMMM '. . 0 d C O CO k a : U) k v 1` > .0 0. till ,� W c o 17 N r. -0 co ' a LL O CO = N 4 Y N Q in OE c% 00 a) ch O a0 Lr C oo �/ NQJJ J CU) IC) a a NdLQ N Q • v- c y LO C CCMH •, 'C EdCD N o0a •No tic ci 0cWd y * O O -'- - ---. o C a Z -I C = ' •C o U) N y' J p j 0' * CO CN1 h a o a) 1 .c W = d 13 = � � LL n o " o re D O a a cNv .- a) c a) � w .- LLI 0 U U) . E a) F- O C° ca CO 0 E E > w °i a W 0 g , 0 0 co 0 ' U Y p H N N- H p LL m ° Wto tji ti.C). o Lon x �� H 0) c- 00 m N �� LL ca poo J Ln p o r c d N -- o , .- O ,4„ o 17 w 207p C1 c M T- - �co " oo L-J o N LL r E V N O II N CD ncu N m N w p 0..0 � � rn a- 77_ Q � _ c +' m O o0 0 c::, in 3 LL N- v ` C o 0 0 o N F a p N- f- •-' � N- T- o o 0 N C7 ,- Z CUr. to o N w ,_ Ca o N j .O C) M CD CO N ('� J V m Imo- y „I' 1.. .. .. �' Z Co Q O`1.0 N L V) E o m 'S ( C7) co R U > E N > -- C i K 2 I .( y cp h m -PA 0 o 0 0) j `- aC`c LIJ ca w a j o Q l0 O• o C) O X _ m ce O E N - O. co 9 . = d 0 w ,= a ,co U) N J 0 0 0 0 0 0 0 0 0 N E N I� N Y U C) W e 0N) 00) N 0 N O u) CO co in re O 11 a) C) m 321flSS id E 3 o I w 0 Cement Detail Report CD5-17 4,1 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL,4/23/2017 08:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/28/2017 03:30 4/28/2017 06:00 CD5-17 Comment Pumped 75 bbl 11 ppg MudPushll,302 bbl 11 ppg Lead cement,60.8 bbl 15.8 ppg tail cement.Bumped plugs and floats held.No losses. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement to surface 36.6 2,232.0 Yes 110.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 7 540.0 1,030.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 75 bbl 11 ppg MudPushll,302 bbl 11 ppg Lead cement,60.8 bbl 15.8 ppg tail cement.Bumped plugs and floats held. 110 bbl 11 ppg lead to surface. No losses. Cement Fluids&Additives Fluid - Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement 36.6 1,732.0 1,001 G 302.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.76 11.00 252.0 4.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.5 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,732.0 2,232.0 290 G 60.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 143.0 4.25 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 9/25/2017 • ! CD5-17_7-5/8"Intermediate casing Well: CD5-17 7 5/8"29.7#L80 BTC-M, TXP&H, 563 Dopeless Casing Date: ConocoPhillips °oyonl9 Alaska,Inc. Depth Jt Number Joints Well Equipme .:,1 _ ..:pdtonand Comments Length Tops Page 1 RKB to Top;,7►f String or RKB to Lock Down; crews RKB to LLDS ' ' . ,,;,` ` 34.08 FMC 7.625"fluted hanger .72 34.08 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.36 34.80 Jts 338 to 392 55 Jts 7-5/8", 29.7#, L-80 H563 Dopeless Casing 2219.42 37.16 7-5/8", 29.7#, L80 XO jt , H563 DPLS box X TXP pin 34.50 2256.58 Jts 247 to 337 91 Jts 7-5/8", 29.7#, L80, TXP Casing 3638.38 2291.08 7-5/8" HES Cementer Stage Collar (Qannik top 5765')(Qannik net base 5927) 3.07 5929.46 Jts 31 to 246 216 Jts 7-5/8", 29.7#, L80, TXP Casing 8639.51 5932.53 7-5/8", 29.7#, L-80 BTC-M Pup 20.17 14572.04 Jts 30 to 30 1 Jts 7-5/8", 29.7#, L80, BTC-M Casing with RA Tag in Coupling 40.39 14592.21 Jts 28 to 29 2 Jts 7-5/8", 29/#, L-80 BTC-M Casing 81.09 14632.60 Jts 257:002267 1 Jts -518i", 29.7#, ..-80 BTCM'Casing Wh1;1 s'to .J't4 Wce1 tral) m, '' 40.14 14713.69 Jts 22 Jts 7-518", 29.7#, L-80 BTC-M Casing 884.09 14753.83 7-5/8", 29.7#, L-80 BTC-M Pup 10.41 15637.92 7-5/8", 29.7#, L-80 BTC-M Pup 20.07 15648.33 Jts 4 to 4 1 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 38.10 15668.40 7-5/8" HES Baffle Collar 1.19 15706.50 Jts 3 to 3 1 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 39.47 15707.69 7-5/8" HES Float Collar 1.51 15747.16 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC-M Casing 79.30 15748.67 7-5/8" HES Eccentric Nose shoe 2.65 15827.97 15830.62 Alpine C Top at 14,710' MD/7,484' TVD 15830.62 TD 9-7/8" Hole at 15,846' MD/7,606' TVD (10.5" Hole to 15,745') 15830.62 Casing Shoe at 15,831' MD/7,605' TVD 85° Inc 15830.62 1 Centek 10' up from shoe w/stop ring on Jt#1 15830.62 1 Centek 30' up from shoe w/stop ring on Jt#2 15830.62 3 Centeks per 2 joints from#3 -#22, stops at 27', 13' as per schedule. 15830.62 1 Centek on jts#23 above stop ring 13' from pin 15830.62 No centralizer on jt#24,#25,#26 and#27 15830.62 3 Centeks per 2 joints from#28-#62, stops at 27', 13' as per schedule. 15830.62 '3 Centeks per 2 joints#248 -#262, stops at 27', 13' as per schedule. 15830.62 1 Centek per joint ,XO, #338, #339 15830.62 1 Straight Blade Centralizer on every other joint from #341 -#391 15830.62 Total Centralizers"(Centeks,= 113, Straight blades=26) ,. 15830.62 Remarks: Baker Lock shoe track to pin of joint#4, Baker Lock stage collar of#246&pin of joint#247 Up Wt NA K M/U Tq for 7-5/8"TXP 21,290 ft/lbs Jnts 102-337 Dn Wt ??? K M/U Tq for 7-5/8" HYD563 DPLS 12,400 ft/lbs Jnts#338-392 Block Wt 60 K Avg. M/U Tq for 7-5/8"BTC-M w/Volant=9,400 ft/lbs Jnts#1-101 Rig Supervisors: • Jt Number Joints Well Equipment Description and Comments Length Tops Page 2 Extra XO 563 Box x BTC Pin 2.05' 15830.62 15830.62 15830.62 Pups BTCM 15830.62 20.07 15830.62 10.41 15830.62 7.71 15830.62 5.67 15830.62 20.17 15830.62 15830.62 Pups Hyd 563 15830.62 19.58 15830.62 9.85 15830.62 5.93 15830.62 4.86 15830.62 15830.62 15830.62 Centralizers 15830.62 111) Centeks, SII #0758-0978S, 7-5/8" x 9-7/8" 15830.62 27) Ray Oil Tool, #4830-9S, 7-5/8" x 9-5/8" x 8" 15830.62 15830.62 15830.62 Extra BTCM Jts Outside= 5 15830.62 Extra 563 outside=9 15830.62 Extra TXP outside=10 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 15830.62 Remarks: Rig Supervisors: Security Level: AK Development • Daily Drilling Report (No Costs) 11) 1140 aj.: 0 CD5-17 CorocaPh iuips Report Number: 18 Rig: DOYON 19 Report Date: 5/10/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-17 Development 16.10 18.0 0.00 15,846.0 15,846.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/23/2017 4/25/2017 42.06 39.23 2.83 6/1/2017 Last Casing String SURFACE,2,222.5ftKB Ops and Depth @ Morning Report 24hr Forecast RIH with 7 5/8"Csg @ 13,200'MD Continue running 7 5/8"casing and land. Circulate and condition mud. R/U and pump 2 stage I .Cmt job. Last 24hr Summary RIH with 7 5/8"casing from surface to 10,936'MD as per tally. General Remarks Weather Head Count No AIS,Rig and Camp on Hi Line power @ CD5. Cloudy,20°F,Wind NE 12 mph,WC8,Vis 10 51.0 mi Supervisor Title Rick Bjorhus Rig Supervisor Andy Marushack Rig Supervisor Diana Guzman Rig Engineer Kurt Alexa Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code` Activity Code -T-X- -"Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 12:00 12.00 INTRM1 CASING PUTB P 0.0 5,665.0 RIH with 7 5/8"casing as per tally to 5,665'MD. M/U shoe track w/ Bakerlok and verified floats held. Installed bow spring centralizers 3/2 joints from shoe track to 2580'while RIH. No centralizers on jnts#24-27 for whipstock and window. 12:00 13:00 1.00 INTRM1 CASING CIRC P 5,665.0 5,705.0 Circulated BU.Staged pumps up to 5.5 bpm w/220 psi. P/U=175, S/O=140. 13:00 19:30 6.50 INTRM1 CASING PUTB P 5,705.0 9,256.0 Continue RIH w/7 5/8"casing f/ 5,705'to 9,256'MD. S/O=150. 19:30 20:00 0.50 INTRM1 CASING CIRC P 9,256.0 9,256.0 Broke circulation and pumped 50 bbl staging up to 3 bpm,200 psi. P/U=300,S/O=150. 20:00 00:00 4.00 INTRM1 CASING PUTB P 9,256.0 10,936.0 Continued RIH f/9,256'to 10,936'MD. Installed HES Stage tool and Bakerloked pin/box. Installed bow spring centralizers 3/2 jts from jt#247-259. Mud Check Data YP Cale Gel(1os) Get(10m) ,Gel(30m) HTHP Filtrate ' • - Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(slgt) pv Caic(cP) '(Ibf/1ow)_ (Ibf/100fN) (Ibf/100ft') (lbf/100ft°j; MET(Iblbbl) (mLf3Omin) pit ('F) (%) Low Solids 15,846.0 10.80 45 15.0 28.0 12.0 14.0 16.007 22.5 0.0 9.5 80.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 45 14.0 30.0 12.0 14.0 18.007 22.5 0.0 9.6 80.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 45 12.0 29.0 10.0 14.0 18.007 22.0 0.0 9.6 80.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 45 13.0 31.0 12.0 15.0 18.007 22.0 0.0 9.6 92.0 14.3 Non- Dispersed Latest BOP Test Data to 250/3500 nsi Shut Annular and tested Com 5/9/2017 C'hanaed nut ton rams to 7 5/8"and tested against 7 5/8"test joint to 250/2500 nsi Tests Page 1/2 Report Printed: 9/2512017 Security Level: AK Development Daily Drilling Report (No Costs)" CD5-17 Citli Report Number: 18 Rig: DOYON 19 Report Date: 5/10/2017 Injection Fluid Fluid Source From Lease(bbl) Deaf Vendor _ Manifest Number ..,,.�; " Note Water Based Mud CD5-17 258.0 CD1-01 AES 483598 CD5-17 source well Wellbores Wellbore Name Wellbore API/UWI CD5-17 501032075400 Section Des Size(in) Act Top(RKB) Act Btm((KB) -Start Date "S End Date CONDI 20 36.6 114.0 4/4/2017 4/4/2017 SURFAC 131/2 114.0 2,232.0 4/25/2017 4/29/2017 INTRM1 101/2 2,232.0 15,831.0 4/29/2017 5/15/2017 PROD1 6 3/4 15,831.0 28,645.0 5/15/2017 6/11/2017 Page 2/2 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs CD5-17 CtocoPhil)i Report Number: 19 AL k_ Rig: DOYON 19 Report Date: 5/11/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-17 Development 17.10 19.0 0.00 15,846.0 15,846.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/23/2017 4/25/2017 42.06 40.23 1.83 6/2/2017 Last Casing String INTERMEDIATE, 15,830.6ftKB Ops and Depth @ Morning Report 24hr Forecast R/D cmt tools and installing packoff. Open stage tool and pump 2nd stage cmt. R/D cmt equipment and install pack off. UD 5"DP. Last 24hr Summary Landed 7 5/8"casing at 15,831'MD. Circulated and conditioned mud. Pumped 184 bbls of 15.8 ppg first stage cmt and started displacement. General Remarks Weather Head Count No AIS,Rig and Camp on Hi Line power @ CD5. Cloudy,21°F,Wind NE 15 mph,WC 7,Vis 10 51.0 7 5/8"Casing Costs Added mi Supervisor .. .. Title _ _ Rick Bjorhus Rig Supervisor Andy Marushack Rig Supervisor Diana Guzman Rig Engineer Kurt Alexa Drilling Engineer Time Log Start Time End Time Dur(hr) Phase " Op Code " Activity Code I-T-X Trbl Code Trbl Class Start Depth(ftKE) End Depth(ftKB) Operation 00:00 04:00 4.00 INTRM1 CASING PUTS P 10,936.0 12,981.0 RIH f/10,936'to 12,981'MD with 7 5/8"casing. 04:00 04:30 0.50 INTRM1 CASING CIRC P 12,981.0 12,981.0 Break circulation w/1.5 bpm,420 psi and attempt to reciprocate pipe. worked up to 435k P/U and decided to continue running casing. 04:30 13:30 9.00 INTRM1 CASING PUTS P 12,981.0 15,793.0 RIH w/7 5/8"casing f/12,981'to 15,793'MD as per tally. SIO=125. 13:30 14:00 0.50 INTRM1 CASING HOSO P 15,793.0 15,831.0 M/U hanger and landing joint. Land casing @ 15,831'MD,S/O= • 125. 14:00 21:00 7.00 INTRM1 CEMENT CIRC P 15,831.0 15,831.0 Circulate and conditioned mud for cmt job. Staged pumps up from 1/2 bpm to 8 bpm as old mud was circulated out,425-810 psi. Attempted to reciprocate pipe w/ 425k P/U with out breaking over. SimOps,rigged up cmt lines. 21:00 23:00 2.00 INTRM1 CEMENT CMNT P 15,831.0 15,831.0 Held Prejob,tested lines to 4000 psi,and pumped 40 bbl of 12.5 ppg MudPush II at 4 bpm. Dropped bottom dart and chased with 184 bbl of 15.8 ppg cmt at 4.8 bpm,400 psi. Dropped top dart and chased with 10 bbl of water from the cmt unit. 23:00 00:00 1.00 INTRM1 CEMENT CMNT P 15,831.0 15,831.0 Start displacement with 10.8 ppg LSND at 8 bpm,420 psi. Pumped 380 bbl. Mud Check Data YP Cat Gel(10s) Gel(10m) Gel(30m): ;" HTHP Filtrate Density Temp Solids,Com. Type . Depth(EKE) Dens(lb/gal) Vis(s/qt) PV,Calc(cP) .i (lbf/100f19 (tbf/100(ts) (lbf/100ft) (Ibf/100ft'). MET(Iblbbl) (mL73Omin) pH' CF) (TO Low Solids 15,846.0 10.80 40 12.0 23.0 9.0 11.0 13.005 23.0 0.0 9.5 80.0• 14.3 Non- Dispersed Latest BOP Test Data 5/9/2017 Chanced out ton rams to 7 5/8"and tested against 7 5/8"test iointrto 250/3500 nsi Shut Annular and tested to 250/2500 nsi Tests Date Page 1/2 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs CD5-17 rtarctoao 'hi[lips Report Number: 19 Rig: DOYON 19 Report Date: 5/11/2017 Mud Check Data. YP CalcGet(10s) Gel(10m)' Gel(3Qm) HTHP Filtrate Density Temp Solids,Com. Type -: Depth(EKE) Dens,(lb/gal) Vis(slit) PV Cabo(cP) (ibf/100fF)" '(Ibf/100fF) (Ibf/100fF) (Ibf/100tt') MBT(lb/bbl) (mL/30min) ; pH "(`F) _-(%) Low Solids 15,846.0 10.80 47 13.0 27.0 10.0 12.0 14.006 23.0 0.0 9.5 75.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 42 13.0 23.0 8.0 11.0 14.006 22.5 0.0 9.6 75.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 44 13.0 27.0 10.0 12.0 14.006 22.5 0.0 9.6 76.0 14.3 Non- Dispersed Injection Fluid Fluid •i Source From Lease(bbl) Dest Vendor , 'Manifest Number ', - _ Note + • Water Based Mud CD5-17 275.0 CD1-01 AES 483600 CD5-17 source well Welibores a Wellbore Name Wellbore API/UWI CD5-17 501032075400 Section Des Size(in) Act Top(ftKB) Act=Btm(ftkB) Start Date End Date CONDI 20 36.6 114.0 4/4/2017 4/4/2017 SURFAC 131/2 114.0 2,232.0 4/25/2017 4/29/2017 INTRM1 101/2 2,232.0 15,831.0 4/29/2017 5/15/2017 PROD1 6 3/4 15,831.0 28,645.0 5/15/2017 6/11/2017 Casing Strings ;- Csg Des Run Date OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Comp,-- INTERMEDIATE 5/11/2017 7 5/8 29.70 L80 15,830.6 113 Centek and 26 strait blade centralizers. Cement Intermediate Casing Cement -Started @ 5/11/2017 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-17 INTERMEDIATE,15,830.6ftKB Full Returns Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 13,300.0 15,830.0 8 700.0 Fluid,! Class` Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) Yield(fF/sack)' Est Top(ftKB) Est atm(1113) Intermediate Cement G 888 184.0 15.80 1.16 13,300.0 15,830.0 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Casing Cement 5,265.0 5,929.0 8 400.0 • Fluid ' , Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) ';Yield(ft'/sack) 1; Est Top(ftKB) - Est Btm(EKE) Intermediate Cement G 237 48.0 15.80 1.16 5,265.0 5,929.0 Page 2/2 Report Printed: 9/25/2017 Security Level: AK Development •k � �a Daily Drilling Report (No Costs CD5-17 ConocoPhillips toio- .;371 Report Number: 20 Rig: DOYON 19 Report Date: 5/12/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-17 Development 18.10 20.0 0.00 15,846.0 15,846.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/23/2017 4/25/2017 42.06 41.23 0.83 6/3/2017 Last Casing String INTERMEDIATE, 15,830.6ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE Test BOPE. Slip and cut DL. M/U 6 3/6"Drilling BHA and RIH. Last 24hr Summary Pumped the 2nd stage intermediate cement job,installed packoff,and rigged down. L/D 5"DP from derrick. Changed out saver sub. General Remarks Weather Head Count No AIS,Rig and Camp on Hi Line power @ CD5. Cloudy,23°F,Wind NE 16 mph,WC 10,Vis 51.0 10 mi Supervisor Title Rick Bjorhus Rig Supervisor Andy Marushack Rig Supervisor Diana Guzman Rig Engineer Kurt Alexa Drilling Engineer Time Log Time P Start Time End Time Dur(Er) Phase !- Op Code Activity Code -T-X '.Trbl Code - Trbl Class Start Depth(EKE) End Depth(EKE) Operation 00:00 01:00 1.00 INTRM1 CEMENT CMNT P 0.0 0.0 Finish displacing 1st stage cmt w/ 8 bpm,400-1130 psi.Slowed the last 15 bbl to 3 bpm and bumped plug @ 7102 stks. Pressured up to 1200 psi and held for 5 min. Bleed off and checked floats. floats held. 01:00 02:15 1.25 INTRM1 CEMENT CIRC P 0.0 0.0 Pressured up to 3090 psi and opened stage tool as per HES. proceeded to pump 550 bbl surface to surface at 8 bpm,510 psi. 02:15 04:00 1.75 INTRM1 CEMENT CMNT P 0.0 0.0 Pumped 40.1 bbl of 12.5 ppg MudPush II followed by 48 bbl of 15.8 ppg cmt. Dropped closing plug and chased with 10 bbl of water. Swapped over to rig pumps and displaced at 8 bpm, 300-600 psi. Slowed pumps to 4 bpm and landed plug at 2619 stk. Pressured up to 2000 psi to close stage tool and held for 5 min. Bleed off and confirmed tool closed. "CMT IN PLACE 03:45" 04:00 04:30 0.50 INTRMI CEMENT RURD P 0.0 0.0 B/D cmt lines and R/D cement equipment. Back out landing joint and L/D. Drained stack. 04:30 06:00 1.50 INTRM1 CEMENT WWSP P 0.0 0.0 Retrieved wear ring and installed packoff as per FMC. Tested packoff to 5000 psi for 10 min. SimOps,LID Volant tool,R/U 5" elevators,and removed skate roller. 06:00 23:45 17.75 INTRM1 CEMENT PULD P 0.0 0.0 LID 20 jts of 5"HWDP,jars,and 160 stands of 5"DP. SimOps, ball mill performed freeze protect w/84 bbl of diesel. 23:45 00:00 0.25 INTRM1 CEMENT RURD P 0.0 0.0 Changed out saver sub from 5"to 4"XT-39. Latest BOP Test Data Date I Corn 5/P/2017 Chanced out ton rams to 7 5/8"and tested against 7 5/8"test ioint to 250/3500 nsi Shut Annular and tested to 250/2500 osi Tests Page 1/2 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs CD5-17 ComociIli Report Number: 20 Rig: DOYON 19 Report Date: 5/12/2017 Mud Check Data YP Calc Get(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Com. Type ( 4r) T e"- �% Depth(ftke) Dens Ib(gal) V�(s/qt) PV CMG(cP) (1b0100fL') (Ibfr100ft=) jlbf/t00ft.) (lbf/100ft.) MBT(I6/bbl) (mU30mn) pH 1 CF) - (!) Low Solids 15,846.0 10.80 44 13.0 26.0 10.0 11.0 13.005 23.0 0.0 9.5 62.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 44 13.0 25.0 8.0 10.0 13.005 23.0 0.0 9.5 70.0 14.3 Non- Dispersed Low Solids 15,846.0 10.80 44 13.0 25.0 8.0 10.0 13.005 23.0 0.0 9.5 70.0 14.3 Non- Dispersed Low Solids 15 846.0 10.80 42 13.0 24.0 3.0 11.0 13.005 23.0 0.0 9.7 93.0 14.3 Non- Dispersed Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Water Based Mud CD5-17 275.0 CD1-01 AES 483506 CD5-17 source well Water Based Mud CD5-17 275.0 CD1-01 AES 483505 CD5-17 source well Water Based Mud CD5-17 275.0 CD1-01 AES 483504 CD5-17 source well Welibores Wellbore Name Wellbore API/UWI CD5-17 501032075400 Section Des Size(in) - Act Top(MB)- Act Still(EKE) ; Start Date ' End Date" CONDI 20 36.6 114.0 4/4/2017 4/4/2017 SURFAC 131/2 114.0 2,232.0 4/25/2017 4/29/2017 INTRM1 101/2 2,232.0 15,831.0 4/29/2017 5/15/2017 PROD1 6 3/4 15,831.0 28,645.0 5/15/2017 6/11/2017 Page 2/2 Report Printed: 9/25/2017 Y pr OOO flit 000 000O LnOOOOOO Ln 0 0 Ln Ln In 'r r) oo coN N CV N N Y • I` CO CO 4. 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N w .c •O Q U LL N W O U L- m m (T 51- o I- Cl) o N a a) U •E � a`) a a) Ea� ca 0 a) _ >Z L (a t = 73 N a) 0 0 o t/) E Ca ' ) m O Q O CA O) `al)) W J o 0 H N C N a) Z = 'C Ce w v = 321t1SS321d E o 2 o 0 2 w0 • Cement Detail Report 4*-0- CD5-17 Carxxx,Phillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/23/2017 08:00 Cement Details ' Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/11/2017 20:40 5/12/2017 03:50 CD5-17 Comment Pumped 40 bbl of MPII,dropped bottom dart,and pumped 184.3 bbl of 15.8 ppg cement. Dropped top dart and displaced. Bumped dart and floats held. Pressured up and opened stage tool. Pumped 40 bbl of MPII and 48 bbl of 15.8 ppg cmt. Dropped closing plug and bumped. Shifted the stage tool closed and checked at surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement intermediate, 13,300.0 15,830.0 Yes Yes Yes Cement 500'above Kup C Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 8 7 700.0 1,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Drill Bit 6 3/4 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 13,300.0 15,830.0 888 G 184.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 105.0 6.25 Additives Additive Type Concentration Conc Unit label D046 AntiFoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.03 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Isolate Qannik,500' 5,265.0 5,929.0 Yes Yes No Cement above Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 8 7 400.0 2,000.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Drill Bit 6 3/4 Comment Cement Fluids&Additives �o ,If Fluid ,..... Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,265.0 5,929.0 237 G 48.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 124.0 4.91 Additives Additive Type Concentration Conc Unit label D046 AntiFoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.01 gal/sx Page 1/1 Report Printed: 9/25/2017 0 • Additional information regarding CD5-20 410 • CD5-20 10 3/4"Surface Casing Well: CD5-20 10-3/4" 45.5# L-80 H d 563 DPLS Casin• Date: 1/24/2017 ConocoPhillips Rig: Doyon 19 Alaska,Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws • . Doyon 19 RKB to top of Landing Ring 36.38 FMC 10-3/4" Casing Hanger .18 36.38 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt, Pin X Pin 2.25 36.56 Jts 5 to 56 52 Jts 10-3/4", 45.5#, L-80, HYD563 DPLS Casing 2128.77 38.81 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt (Doped) 19.38 2167.58 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt (Doped) 4.81 2186.96 Jts 3 to 4 2 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 81.08 2191.77 10-3/4" HES Float Collar 1.45 2272.85 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 80.54 2274.30 10-3/4" HES Composite Shoe 2.82 2354.84 2357.66 2357.66 2357.66 2357.66 10-3/4" Shoe at 2,358' MD /2,183' TVD 2357.66 13-1/2" TD at 2,368' MD /2,190' TVD, 10' rathole 2357.66 2357.66 2357.66 BakerLok pin end of jnts 2,3, and 4 2357.66 2357.66 2357.66 1 Centek 10' up from shoe w/stop rings on Jt#1 2357.66 1 Centek 30' up from pin w/stop rings on Jt#2 2357.66 1 Centek 20' up from pin w/stop rings on Jt#3 2357.66, 1 Centek on Jt#4 Floating 2357.66 1 Centek on 20' Pup Joint Floating 2357.66 1 Centek every joint from #5 to#55 Floating 2357.66 2357.66 2357.66 2357.66 Total Centralizers = 56 Centeks 2357.66 Centek, SII, 10-3/4"x 13-1/2", PN 1034-1312S 2357.66 2357.66 2357.66 2357.66 Remarks: Use Seal Guard ECF on HYD 563 Up Wt K MU Tq with Volant-trq for Hyd 563 dpls 19.4K ft/lbs Down Wt K Jts Bakerlocked to pin end of#4 Block Wt 60 K Drifted with 9.885"drift Rig Supervisors:K.Harding/A.Marushack Security Level: AK Development Al • Daily Drilling Report(No Costs ' =enoir CD5-20 Report Number: 4 Con000Philiips Rig: DOYON 19 Report Date: 1/24/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-20 Development 2.73 4.0 0.00 2,368.0 2,368.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 1/21/2017 1/22/2017 44.13 41.55 2.58 3/3/2017 Last Casing String SURFACE,2,357.7ftKB Ops and Depth @ Morning Report 24hr Forecast M/U Intermediate BHA while WOC. L/D casing running and cement tools,service rig,and M/U Int.BHA while WOC. N/D annular and N/U BOPE and test. Last 24hr Summary Ran 10 3/4"Casing to TD @ 2357.66'MD. Circulated and conditioned mud. Pumped 289 bbl of 11 ppg lead and 58 bbl of 15.8 ppg tail cement and displaced. Plug bumped and 162 bbl of cement was returned to surface. Shut in annular and WOC.Performed BOPE BWM offline. General Remarks Weather Head Count No AIS. Rig and Camp on highlne power. Fair,-29°F,Wind NE @ 6 mph,WC-46°,Vis 50.0 10 mi : SupeMsor. TW Ken Harding Rig Supervisor Andy Marushack Rig Supervisor Joseph Engel Rig Engineer Weifeng Dai Drilling Engineer Hanna Sylte Completions Engineer Time e Cog - Start Time End Time Dur(hr) Phase "' Op Code j Activity Code -T-X" 'Trbl Code Trbl Class Start Depth(ftKB)' 'End Depth(ftKB) Operation 00:00 01:30 1.50 SURFAC CASING BHAH P 92.0 0.0 L/D surface BHA as per SLB 01:30 04:00 2.50 SURFAC CASING RURD P 0.0 0.0 P/U casing running tools and rig up Volant,bails,and side door elevators. Clean and clear rig floor. 04:00 09:15 5.25 SURFAC CASING PUTB P 0.0 1,503.0 M/U 10 3/4"shoe track,check floats,and RIH with surface casing to 1,503'MD. S/O=100. 09:15 10:00 0.75 SURFAC CASING CIRC P 1,503.0 1,503.0 Break circulation and pump BU below the permafrost. gradually built rate up from 2 bpm to 8 bpm,140-210 psi. P/U=110, S/O=100 10:00 12:00 2.00 SURFAC CASING PUTB P 1,503.0 2,318.0 Continue RIH with 10 3/4"casing f/1,503'to 2318'MD. S/0=125 12:00 12:30 0.50 SURFAC CASING HOSO P 2,318.0 2,358.0 M/U Hanger and two piece landing joint and land surface casing at 2,358'MD. 12:30 15:45 3.25 SURFAC CEMENT CIRC P 2,358.0 2,358.0 Circulate and condition mud for cement job,staging pumps up to 8.5 bpm,550 psi,P/U=144, SIO=139. 15:45 16:15 0.50 SURFAC CEMENT OWFF P 2,358.0 2,358.0 OWFF,well static. B/D TD,close IBOP,and R/U cement lines. 16:15 16:30 0.25 SURFAC CEMENT SEQP P 2,358.0 2,358.0 Flood cement lines and pressure test to 2500 psi. Latest BOP Test Data Page 1/3 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs CD5-20 Report Number: 4 GtmocoPhillips P Rig: DOYON 19 Report Date: 1/24/2017 Time Lo 9 ._ (h) Op Time P Start Time •End Time DU r Phase Code Activity Code T-X --Trbl Code: .Trbl Class Start;Depth(ftKB).. End Depth(ftKB) `: Operation 16:30 20:15 3.75 SURFAC CEMENT CMNT P 2,358.0 2,358.0 Dowell pumped 55.5 bbl of 10.5 ppg mud push. Shut down to thaw out frozen cement lines then dropped bottom plug. Pumped 289.8 bbl of 11 ppg(1.91 yld)lead cmt,followed by 58.1 bbl of tail 15.8 ppg(1.16 yld)cement at 5 bpm. Loaded top plug and flushed lines w/20 bbl of water from cmt pumps. Swapped over to rug pumps and displaced w/ 198 bbl of 10 ppg mud at 8 bpm and slowed to 3 bpm before plug bumped at 1975 stks with 500 psi. Pressured up to 1000 psi and held for 5 min. bleed off pressure and checked floats, floats held. 162 bbl of cement was returned to surface(First 30± bbls contaminated interface). Cement in place @ 20:10.Full returns. 20:15 21:30 1.25 SURFAC CEMENT RURD P 2,358.0 2,358.0 Rig down cmt.equipment and flush riser with black water. functioned annular 3X and shut in at 20:52 to monitor pressure. R/D hoses,Volant,and bail extensions. B/D TD. 21:30 23:00 1.50 SURFAC CEMENT WOC P 2,358.0 2,358.0 Perform derrick inspection, greased TD and elevators. Cleaned and cleared rig floor. SimOps,WOC. 23:00 00:00 1.00 SURFAC CEMENT WOC P 2,358.0 2,358.0 Slip and Cut 45'of drill line. SimOps,WOC Mud Check Data - .. YP Calc -Gel(10s) Gel_ (10m)-' . Gel(30m}. HTHP FiltrateDensity Temp Solids,Co ,rr 7Type, Depth(ftKB) Dens(lb/gal) Vis(s/gt) PV Cain(PP) (lbf/100fP).. "(lbf/100ft') (lbf/100ft) (Ibf/100fV)t MBT(lb/bbl) (mL/30min) -pH - ("F) _ ;(%) DRILPLEX 2,368.0 10.00 10.0 17.0 6.0 12.0 13.005 16.0 0.0 10.3 66.0 9.3 DRILPLEX 2,368.0 10.00 10.0 18.0 25.0 34.0 39.016 16.0 0.0 10.8 67.0 9.3 DRILPLEX 2,368.0 10.00 11.0 33.0 42.0 51.0 56.023 17.5 0.0 10.8 66.0 9.3 DRILPLEX 2,368.0 10.00 11.0 34.0 36.0 42.0 46.019 17.0 0.0 10.9 70.0 9.5 Drill',Strings;: SHA No,1 - Surface ! Bit Run No.-1 131/2in,VM-3,,5262173 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 0.0 2,368.0 0.76 15/16/16/16 1-4-WT-A-F(#3)-2-NO-TD 3 Drill String Components Jts _ ftem Des ..•OD(tit) lD(i ,Top Conn Sz(in}:: Top Thread Cum Len(ft) 49 Drill Pipe 5 4.276 4 1/2 IF 1.05 8 5"HWDP x 8 5 3.000 4 1/2 IF 245.74 1 Drilling Jars-Hydraulic 6 1/4 2.250 4 1/2 IF 276.14 13 5"HWDP x13 5 3.000 4 1/2 IF 673.76 7"Saver Sub 7 2.880 4 1/2 IF 677.31 1 6 7/8"NMDC 6.7 2.875 4 1/2 IF 708.04 1 6 7/8"NMDC 6.85 2.875 4 1/2 IF 738.46 8 1/4"NM XO 8 2.810 4 1/2 IF 742.87 Page 2/3 Report Printed: 9/25/2017 • • Security Level: AK Development .x is Daily Drilling Report (No Costs) CD5-20 ConoociPhiilig,s, Report Number: 4 Rig: DOYON 19 Report Date: 1/24/2017 Drill String Components Jts iItem Des_:. 8 1/4"NM UBHO 8.1 2.875 6 5/8 Reg 746.58 1 8 1/4"MWD 8.4 5.109 6 5/8 Reg 775.30 1 8"Pony Drill Collar 8 2.813 6 5/8 Reg 785.31 1 8"Pony Drill Collar 8.38 2.875 6 5/8 Reg 794.99 12 1/8"NM Stabilizer,Ported float 8.35 2.880 6 5/8 Reg 803.00 8-1/4"PDM 8 1/4 2.125 6 5/8 Reg 834.70 Drilling Parameters >.., Flow Rate m i End DepthSliding (gpm) WOB RPM PU'Str Wt 7 $t(Y/t SOit P Start(ftKB) (ftK ;_ Cum Depth(ft) Cuin Drill Time(60 ,.Time(hr) (gPm) (10001bf) (rpm) - SPP(psi) (1000lbt) •��/!" ibt), (1 r, ',O#,0 . • ° Dill!Tq E'.. 2,368.0 2,368.0 2,368.00 17.15 0.00 0 0 0 0.0 0 0 0 0.0 0.0 Wellbores Wellbore Name Wellbore API/UWI" CD5-20 501032075200 •,Section Des ' 'Size(in) Act T4 ( B) ••,..it Act Sac(RKB) StartDate End Date CONDI 24 36.5 115.0 3/5/2016 3/5/2016 SURFAC 13 1/2 115.0 2,357.7 1/22/2017 1/26/2017 I NTRM 1 11 2,357.7 12,303.0 1/26/2017 2/8/2017 PROD1 6 3/4 12,303.0 24,119.0 2/8/2017 2/20/2017 Casing Strings ` ,n,., %, » .re :- g ( ) WULen(Ib1R) ; rstte r4 r Set, tb MKS) Com Csg Run Date OD in SURFACE 1/24/2017 10 3/4 45.50 L-80 2,357.7 10 3/4"Surface casing w/56 jts of 10 3/4"45.5#L- 80 HYD563. 56 Centek centralizers. Full returns on cmt. Cementezi -u . .: ,,v,, ,,,, e PHli i?........ . *1 i _._.. ,? ?I":',°i ,:4 Surface Casing Cement -Started @ 1/24/2017 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-20 SURFACE,2,357.7ftKB 162 bbl of cmt.to surface Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.5 2,357.7 3 500.0 Fluid • Class :Amount(sacks), Vol Pumped(bbl) ::=:Dens(lbtgal) Yield(ft./sack) ` " Est Top(ftKB) Est Btm(f1KB) Lead Cement LiteCRETE 934 289.0 11.00 1.91 36.5 1,857.0 Tail Cement G 240 58.1 15.80 1.16 1,857.0 2,357.0 Page 3/3 Report Printed: 9/25/2017 000 ilk OLnC C3 U1.141 Ln Ln U) 000000ilk N Ln 0 r 0 0 0 0)_0) d) CA O) C) O) C) C) n) CA 0 OO N- OCD CO O U) Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ul Y CH CHC G. E R- cc E .p' U) c 0NL0n0 LLU0LO7C U) 0U)) 0 IC) 0LOC) 0LLUU0IC) 0U) 0 > ate—) X• E Q. L C3 CD CDT TNNM 07 �P 'Cf Ln Ln CO CDI� I� COCOCDCDCD co - E E m d 1 3 7 4-. \ U) a U) - 0000 0000 000 O 00 in c:) y� c l* b • N- N- N- CA Ln 00 U) NN CO 0Y- �- N CO O = C>1.Q v N M ' Ln CO CO Imo- 00 00 CD CA CA C)) ' c-on 0 •a y .cn Q Qm CJ CH ,y Or NM 1- LnCOr- OO CAO NM1- Ln O E N ' a a ` T T T .- T r > a J .Lc a) ;,: (a ' •_ 0 00 0 000 0 00 O 0 0 - 0 0 ZD NNNN NNNN NNN O 0CDCA . U) ID c CO CO CO CO CO CO CO CO CO CO CO CO CO CO Ln Ln N C.)— n E m CoQ• MMM MMMM MMM Co MMM E mm nl 4' CD ' 4 A c C) - NM Yr U) CO I- 0000 U) CV CV .a� �_ > O d - > d 1_ m �I ... C _ 0000 0000 000 O 0 (30000 �; n 7, U) CV OOLU Ln LU0L7 OO Ln Ln OLnOL7OCO V1 n 0.' ' CC O (n Mtnl,- O -- MLn N- CD - Co CO CO - 000CO d ..) Ci O c Q ,- r ,- r• e- ,- N N NNMMMM E Eto CD CV CO 000N � CO 000 N 1- 000OONCo E 3 Y a ` r - - - . 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M p 3 CD N O O CC) .0 ~ Ui a-s u)0 .4. r.+ CA v 1 Q c � m � ' M CA N a O N03 Ca— .1 LL t- O V N O H .Ni X CB I~ L U) ++ ❑ N CO a) -- N co n i .0 Cl) _o .Q tco i c a- -- F- 0_J C2 J J � G tC6 � ' =O mo O * Oto u. m O OD cil v o) co O o N cp 4t co 0 Lf) N ++ LC) It O 3 � co �_ Z 0 .cco .0 a `� coo N H 0 in t N I- + O o m �+ +, z co c a a) a) .= o) N ` ❑ caE7, QD CO a 0) V C (A a) a cn >) NH yH U CA _ Ca 0 5 -E 92 > 0 ` K 2 c i. N h. d -p Cl- CD > '�' a N W (O H _- 0 d `�' N = O in 'C CO) M- 0 0 L LL d ° x E O E 73 �• a 0 0 •y +, ) E Cn A W m V 1111 ut J o 0 0 0 0 0 0 0 H N Y UII v U r0') N N U) 0 U) C Z C I CO Ce m 321nss32Jd E E 3 o x° w c0 • Cement Detail Report CD5-20 ConocoPhiilips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/21/2017 00:00 Cement Details,: AilikROAVA '' Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/24/2017 16:20 1/24/2017 20:10 CD5-20 Comment Cement Stages „" • Stage Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 36.5 2,357.7 Yes 162.0 Yes Yes Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 7 500.0 1,000.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 9 7/8 Comment Cement Fluids&Additives ,,„ �. ," Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.5 1,857.0 934 LiteCRETE 289.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.79 11.00 220.0 5.50 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Conc Unit label D167 0.5 %BWOC Additive Type Concentration Conc Unit label D185 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,857.0 2,357.0 240 G 58.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 102.0 5.00 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Conc Unit label D065 0.3 %BWOC Additive Type Concentration Conc Unit label D167 0.4 %BWOC Page 1/1 Report Printed: 9/25/2017 • • CD5-20_7-5/8"Intermediate casing Well: CD5-20 7 5/8"29.7#L80 BTC-M& Hyd 563 Dopeless Casing Date: 2/5/2017 ConocoPhillips r1iI '1! Rig: Doyonl9 Alaska,Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 KB to Top Of R P StringRKBk) or ;to Lock Down Screws" ................... ............................ RKB to LLDS 34.02 N< yz FMC 7.625"fluted hanger .72 34.02 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.21 34.74 Jts 248 to 304 57 Jts 7-5/8", 29.7#, L-80 H563 Dopeless Casing 2302.73 36.95 7-5/8", 29.7#, L80 XO jt , H563 DPLS box X BTC pin 40.54 2339.68 Jts 114 to 247 134 Jts 7-5/8", 29.7#, L80, BTC-M Casing 5364.69 2380.22 7-518"HES temente Stage Cola (Su1i97"fop"7,534`)(Sub97bse'7',565'J 3.06 7744.91 Jts 12 to 113 102 Jts 7-5/8", 29.7#, L80, BTC-M Casing 4095.33 7747.97 Jts 11 to 11 1 Jts 7-5/8", 29.7#, L80, BTC-M Casing with RA Tag in Coupling 40.55 11843.30 Jts 9 to 10 2 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 81.60 11883.85 Jts 8 to 8 1 Jts 7-5/8",=;29 7#, L 80;;BTCM,Cas ng_WhipstockJt(No,Centralizer} 40.51 11965.45 Jts 4 to 7 4 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 161.47 12005.96 7-5/8" HES Baffle Collar 1.19 12167.43 Jts 3 to 3 1 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 39.46 12168.62 7-5/8" HES Float Collar 1.23 12208.08 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC-M Casing 78.53 12209.31 7-5/8" HES Eccentric Nose shoe 2.66 12287.84 12290.50 12290.50 12290.50 12290.50 Alpine C Top at 11,969' MD/7,419'TVD 12290.50 TD 9-7/8" Hole at 12,303' MD/7,445' TVD (11" Hole to 13,202') 12290.50 Casing Shoe at 12,290' MD/7,445' TVD 87.25° Inc 12290.50 12290.50 1 Centek 10' up from shoe w/stop ring on Jt#1 12290.50 1 Centek 30' up from shoe w/stop ring on Jt#2 12290.50 3 Centeks per 2 joints from#3 -#6, stops at 27', 13' as per schedule. 12290.50 1 Centek on jts#7 above stop ring 7'from box 12290.50 No centraUzer on t#7't nd#8p *i <y,. �.�a lz 12290.50 3 Centeks per 2 joints from#9-#28, stops at 27', 13' as per schedule. 12290.50 '3 Centeks per 2 joints#113-#131, stops at 27', 13' as per schedule. 12290.50 1 Centek per joint#247, #XO, and#248 12290.50 1 Straight Blade Centralizer on every other joint from#250 -#302 12290.50 Total Centralizers (Centeks=69,Straight blades=27) " 12290.50 Remarks: Baker Lock shoe track to pin of joint#5 Up Wt NA K Baker Lock stage collar&pin of joint#114 Dn Wt 150 K M/U Tq for 7-5/8"HYD563 DPLS 12,400 ft/lbs Block Wt 60 K Avg. M/U Tq for 7-5/8" BTC-M w/Volant=9,400 ft/lbs Rig Supervisors:K.Harding/R.Reinhardt • • Jt Number Joints Well Equipment Description and Comments Length Tops Page 2 12290.50 Extra XO outside=34.50 12290.50 12290.50 Pups BTCM 12290.50 20.20 12290.50 10.40 12290.50 7.71 12290.50 5.64 12290.50 12290.50 12290.50 Pups Hyd 563 12290.50 19.45 12290.50 9.85 12290.50 5.93 12290.50 4.86 12290.50 12290.50 12290.50 Centralizers 12290.50 69) Centeks, SII #0758-0978S, 7-5/8"x 9-7/8" 12290.50 27) Ray Oil Tool, #4830-9S, 7-5/8" x 9-5/8" x 8" 12290.50 12290.50 12290.50 Extra BTCM Jts Outside = 11 12290.50 1 (34) 41.22 12290.50 2 40.42 12290.50 3 40.41 12290.50 4 40.93 12290.50 5 40.31 12290.50 6 40.39 12290.50 7 40.31 12290.50 8 41.23 12290.50 9 (5) 39.91 12290.50 10 40.05 12290.50 11 40.46 12290.50 12290.50 12290.50 12290.50 12290.50 Remarks: Rig Supervisors:K.Harding/R.Reinhardt • • Jt Number Joints Well Equipment Description and Comments Length Tops Page 3 12290.50 12290.50 Removed Btcm Jts#248-258(11 Jts), shift H563 up when exposed 12290.50 Renumber H563#248 to#315 - Done 12290.50 Replaced Jt# 34(41.22) with spare Jt#1 (38.26) - DONE 12290.50 Replace BL Jt#5(39.91) with spare Jt#9(39.92) - DONE 12290.50 Swap Jts#22(PIP) with Jt#11 - DONE 12290.50 Add stop rings per plan to Jts#113-#131 once row exposed - Done 12290.50 Clean box#113 and pin #114 and stage collar- Done 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 _ 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 12290.50 Remarks: Rig Supervisors:K.Harding/R.Reinhardt • Security Level: AK Development g` Daily Drilling Report (No Costs. CD5-20 eonocoPhitlS f Report Number: 14 hia6y Rig: DOYON 19 Report Date: 2/3/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-20 Development 12.73 14.0 0.00 12,303.0 12,303.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 1/21/2017 1/22/2017 44.13 43.13 1.00 3/5/2017 Last Casing String SURFACE,2,357.7ftKB Ops and Depth @ Morning Report 24hr Forecast P/U and run 7-5/8"BTCM casing @ 400'MD Flush stack,Change rams and test to run 7-5/8"casing.R/U and run 7-5/8"29.7#BTCM/H563 casing. Last 24hr Summary Continue BROOH to shoe.Observe under reamer open at shoe.CBU,OWFF,pump out&L/D BHA.Verify reamer opening on surface. General Remarks Weather Head Count No AIS. Rig and Camp on highline power.Ran on generators from 07:15 to 10:00 hrs for CD5 Fair,-5°F,Wind S 8 mph,WC-20,Vis 10 m 51.0 -K pad electrical maint. Supervisor Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Hanna Sylte Completions Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code; Activity Code -:T X Trbl Code Trbl Class Start Depth(ftKB)', End Depth(EKE) Operation 00:00 01:15 1.25 INTRM1 CASING BKRM T Hole Other 3,933.0 3,652.0 Continue backream out of hole Conditions from 3,933'MD to 3,652'MD @ 850 gpm,3190 psi,140 rpm,5-9k Tq.Pressure up to 3300 psi @ 3,652'and 8k Tq,minor ECD spikes. 01:15 02:00 0.75 INTRM1 CASING CIRC T Hole Other 3,652.0 3,652.0 Circulate 2.5 bottoms up @ Conditions 3,652'MD,850 gpm 3190 psi, 140-180 rpm 5 k Tq.Hole unloaded @ bottoms up from packoff.Large and smaller cuttings on all three shaker decks. 02:00 02:30 0.50 INTRM1 CASING BKRM T Hole Other 3,652.0 3,543.0 Continue backream out of hole Conditions from 3,652'MD to 3,543'MD @ 850 gpm,3170-3200 psi, 140 rpm,4.5-7k Tq.Pressure up and ECD spikes again,unable to pull without packing off. 02:30 04:00 1.50 INTRM1 CASING CIRC T Hole Other 3,543.0 3,543.0 Circulate around 36 bbl 12.8 ppg Conditions NP sweep followed by 2 bottoms up,very little cuttings returns on shakers.Observed cuttings becoming very sticky and dehydrated. Mud engineer observed MBT increased to above 30 after previous circulations.Order dilution mud. 04:00 04:30 0.50 INTRM1 CASING SVRG P 3,543.0 3,543.0 Service and lubricate rig,change out wash pipe on top drive. Monitor well on trip tank,no gain or loss. Latest BOP Test Data 1/26/201 7 Date "Test BOPF w/5""test ioint Annular HCR choke/kill 250/2500 nsi for or 5 min [inner 3 1l2""X 6""VBR's choke valves 1 12.13 14 alit Page 1/3 Report Printed: 9/25/2017 • Security Level: AK Development Daily Drilling Report (No Costs! g CD5-20 Conaa t[r Report Number: 14 i Rig: DOYON 19 Report Date: 2/3/2017 Time Log .,;. � � -. Time P Start Time End Time Our(hr) Phase Op Code Activity Cade -T-X Trbl Code Trbl Class Start Depth(ftKB}I End Depth(ftKB) Operation 04:30 12:00 7.50 INTRM1 CASING BKRM T Hole Other 3,543.0 3,025.0 Continue backream out of hole Conditions from 3,543'MD to 3,025'MD @ 850 gpm,3160-2810 psi, 120- 140 rpm,4.5-7k Tq.Performed 275 bbl dilution @ 3,285'MD. Hole unloaded again @ 3,100'- 3025'MD. 12:00 15:00 3.00 INTRM1 CASING BKRM T Hole Other 3,025.0 2,508.0 Continue backream out of hole Conditions from 3,025'MD to 2,508'MD @ 850 gpm,2810 psi,120 rpm,3.5k Tq. 15:00 15:30 0.50 INTRM1 CASING PMPO T BHA Underrea 2,508.0 2,508.0 Pump out of hole @ 850 gpm, mer pull stabilizer into shoe @ 2,497' MD.Observe overpull of 10k with under reamer hanging up at shoe.Pumps off pull reamer into shoe with slight drag.Drop back down,stage pumps to 300 gpm, 450 psi and able to pull reamer into shoe to 2,450'MD.Drop back down below shoe to circulate. 15:30 16:00 0.50 INTRM1 CASING CIRC T Hole Other 2,508.0 2,508.0 Circulate 30 bbl 12.8 ppg NP Conditions sweep @ 750 grm,2640 psi, reciprocate from 2,460'MD to 2,508'MD,140 rpm 2k Tk. 16:00 16:15 0.25 INTRM1 CASING OWFF P 78.0 Monitor well for flow 10 minutes static at 2,508'MD. 16:15 19:45 3.50 INTRM1 CASING PMPO T Hole Other 2,508.0 910.0 Pump out of hole from 2,508'MD Conditions to 910'MD @ 300 gpm,430 psi. P/U=107k,S/0=105k. 19:45 20:00 0.25 INTRM1 CASING OWFF P 910.0 910.0 Monitor well for flow 10 minutes static at HWDP 910'MD. 20:00 21:00 1.00 INTRM1 CASING TRIP P 910.0 178.0 POOH on elevators racking back HWDP to 178'MD.P/U=85k. 21:00 22:00 1.00 INTRM1 CASING DHEQ T BHA Underrea 178.0 106.0 P/U pup joint to Kelly up on float mer sub.Pull Under reamer to surface @ 106'bit depth.Clean and inspect.Set reamer below table and break circulation with water from pill pit,stage up to 450 gpm 420 psi and observe reamer blades function open confirming reamer had not locked in closed position. SIMOPS-Flush BHA with water. 22:00 00:00 2.00 INTRM1 CASING BHAH P 106.0 78.0 PJSM,lay down BHA#2 from 178'MD to 78'MD. Mud Check Data YP Cala ? 'Gel(10s) Gel(10m) - ,Gel(30m)? HTHP Filtrate Density Temp Solids,Com Type Depth(ftKB) Dens(]b/gal) Vis(skit) PV Calc(cP) €(1bf/100ft)° (Ibf/100ftj (lbf/100ft) _(Ibff100fF) MBT(Ib/bbl) (mL/30min) pH- ('F) (%) Low Solids 12,303.0 10.80 45 17.0 24.0 10.0 15.0 20.008 25.0 6.0 9.7 108.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 42 18.0 25.0 9.0 17.0 26.011 25.0 6.1 9.8 114.0 12.5 Non- Dispersed Page 2/3 Report Printed: 9/25/2017 �,F Security Level: AK Development • ►nm .meq Daily Drilling Report (No Costs CD5-20 ConocoPhiilips Report Number: 14 Rig: DOYON 19 Report Date: 2/3/2017 Mud Check Data YP Calc. Gel(10s) Gel(10m) Gel(30r0)', HTHP Filtrate Density Temp Solids,Com. Type Depth(ftKB) Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (Ibfl100ID) (Ib0100fF) (Ibf/100ft2) (Ibf/100ft) MBT(Ib/bbl) (mL/30min) pH (F) (%) Low Solids 12,303.0 10.80 45 22.0 28.0 12.0 22.0 30.012 34.0 6.2 9.5 118.0 14.3 Non- Dispersed Low Solids 12,303.0 10.80 49 21.0 31.0 12.0 21.0 30.012 30.0 6.4 9.5 115.0 14.3 Non- Dispersed Injection Fluid Fluid Source From Lease]].(bbl) Dest Vendor Manifest Number Note Water Based Mud CD5-20 275.0 CD1-01 AES 477096 Water Based Mud CD5-20 240.0 CD1-01 AES 477095 Water Based Mud CD5-20 238.0 CD1-01 AES 477093 Interval Problems .,.-: ,�h-. ,. Start Date Start Depth(EKE) End Depth(ftKB) Trouble Code €= Trouble Class -I ', i i, Wellbore 2/3/2017 106.0 106.0 BHA Underreamer CD5-20 Wellbores Wellbore Name Wellbore API/UWI CD5-20 501032075200 Section Des Size(in) Act Top(ftKB) Act,Btm(EKE) Start Date End Date CONDI 24 36.5 115.0 3/5/2016 3/5/2016 SURFAC 13 1/2 115.0 2,357.7 1/22/2017 1/26/2017 INTRM1 11 2,357.7 12,303.0 1/26/2017 2/8/2017 PROD1 6 3/4 12,303.0 24,119.0 2/8/2017 2/20/2017 Page 3/3 Report Printed: 9/25/2017 Security Level: AK Development = € t • Daily Drilling Report (No Costs. • CD5-20 Con�000Phillips Report Number: 15 Rig: DOYON 19 Report Date: 2/4/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-20 Development 13.73 15.0 0.00 12,303.0 12,303.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 1/21/2017 1/22/2017 44.13 43.13 1.00 3/5/2017 Last Casing String SURFACE,2,357.7ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating and conditioning for cement job @ 12,290'MD. Continue P/U and run casing to 12,253'MD,M/U hanger and landing joint.Land at 12,290'MD.C&C for cement,perform 2 stage cement job.Rig down,pull thin wear ring,set and test packoff,LID 5"DP. Last 24hr Summary Flush stack,Change rams and test to run 7-5/8"casing.R/U and run 7-5/8"29.7#BTCM/H563 casing to 10,638'MD General Remarks Weather Head Count No AIS. Rig and Camp on highline power. Fair,-10°F,Wind SW 10 mph,WC-28,Vis 10 52.0 m Supervisor ':Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Hanna Sylte Completions Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code , Activity Code -T-X Trbl Code Trbl Class . Start Depth(ftKB); End Depth(ftKB) Operation 00:00 00:30 0.50 INTRM1 CASING BHAH P 78.0 0.0 Continue laying down BHA#2 from 78'MD. 00:30 01:30 1.00 INTRM1 CASING WWWH P 0.0 0.0 Function rams,M/U stackwasher and flush stack @ 650 gpm,340 psi,30 rpm.5k Tq until shakers clean.Blow down top drive and mud line.Lay down stack washer,drain stack and FMC pulled wear ring. SIMOPS-Clean and clear rig floor,prep pump#2 for casing run,clean suction screen. 01:30 02:00 0.50 INTRMI CASING BOPE P 0.0 0.0 Change out 3-1/2"x 6"upper VBR to 7-5/8"SBR. SIMOPS-P/U and R/U Volant CRT and equipment.Continue working on pump#2. 02:00 03:00 1.00 INTRMI CASING BOPE P 0.0 0.0 R/U and test with 7-5/8"test joint. Test annular preveter to 250/2500 psi.Test Upper pipe rams to 250/3500 psi 5 min each charted.Rig down test equipment. SIMOPS-Work on pump#1 clean suction screen and discharge. 03:00 03:30 0.50 INTRM1 CASING BOPE P 0.0 0.0 Pull test plug,FMC install 10.375"ID thin wall wear ring. Lay down test joint. SIMOPS-Continue work on#1 mud pump,C/O valve and spring on discharge. 03:30 04:00 0.50 INTRM1 CASING RURD P 0.0 0.0 Continue rigging up to run 7-5/8" casing,M/U bail extensions, 350T spider slips and 7-5/8" elevators. Latest BOP Test Data I Co 1/26/7017 Date "Test BOPF w/5""test mint Annular HCR choke/kill 250/2500 osi for 5 min honer 3 1/2""X 6""VRR's choke valves 1 12 13 14 alit Page 1/2 Report Printed: 9/25/2017 . Security Level: AK Development Daily Drilling Report (No Costs CD5-20 CccPhi(lps Report Number: 15 Rig: DOYON 19 Report Date: 2/4/2017 Time Log Time P Start Time End Time Dur(hr) ,..'..Phase• Op Code •Activity Code -T-X 'Trbl Code. Trbl Class• Start Depth(ftK8) '•End Depth(flKB) Operation 04:00 04:15 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on running 7-5/8"casing with DDI rig crew,CPAI,DDI casing,HES stage tool. 04:15 12:00 7.75 INTRM1 CASING PUTB P 0.0 5,184.0 P/U and RIH with 7-5/8"29.7#L- 80 BTCM casing,make up shoe track,float collar with baffle adapter,baffle collar.Circulate and check floats.Continue P/U and RIH to 5,184'MD(129 jts) Made up HES stage collar after jt 113.Installing Centek centralizers 3/2 jts per detail. 12:00 16:00 4.00 INTRM1 CASING PUTB P 5,184.0 7,312.0 Continue P/U and run 7-5/8" 29.7#L-80 BTCM casing from 5,184'MD to 7,312'MD. 5/0=125k. 16:00 17:30 1.50 INTRM1 CASING CIRC P 7,312.0 7,312.0 Break circulation,stage up from.5 bpm to 8 bpm 320 psi. P/U=185k,5/0=135k,pumped total 480 bbl reciprocated from 7,312'MD to 7,272'MD. 17:30 00:00 6.50 INTRM1 CASING PUTB P 7,312.0 10,638.0 Continue P/U and run 7-5/8" 29.7#L-80 BTCM casing from 7,312'MD to 9,910'MD.M/U XO to H563 Dopeless casing and continue running to 10,638'MD. Total 264 joints in the hole, S/0=180k. Mud Check Data YP Calc- Gel(10s) : Gel(10m) Gel(30m) - HTHP Filtrate Density Temp Solids,Com, Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(CP) (Ibf/100(f) .(Ibf/100ft') (lbf/100(') ` (Ibfl100fF), MBT(It/bbl) (mU3Omin) pH" (F)` -:(%) Low Solids 12,303.0 10.80 49 16.0 25.0 10.0 17.0 18.007 25.5 6.0 9.4 82.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 45 16.0 24.0 10.0 16.0 19.008 25.0 6.3 9.5 91.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 44 16.0 22.0 9.0 16.0 18.007 25.0 6.1 9.5 94.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 44 17.0 20.0 9.0 15.0 18.007 25.0 6.2 9.6 92.0 12.5 Non- Dispersed Injection Fluid - Fluid 3 Source From Lease(bbl) Cleat Vendor Manifest Number%.i.._ Note r Water Based Mud CD5-20 250.0 CD1-01 AES 477097 Wellbores Wellbore Name Wellbore API/UWI CD5-20 501032075200 Section Des.. Size(in) . Act Top(ftK8) Actgtm(ftK8) Start Date. End Date CONDI 24 36.5 115.0 3/5/2016 3/5/2016 SURFAC 13 1/2 115.0 2,357.7 1/22/2017 1/26/2017 INTRM1 11 2,357.7 12,303.0 1/26/2017 2/8/2017 PROD1 6 3/4 12,303.0 24,119.0 2/8/2017 2/20/2017 Page 2/2 Report Printed: 9/25/2017 Security Level: AK Development Daily Drilling Report (No Costs. CD5-20 Cono€oPhi[lips Report Number: 16 fL�•.km Rig: DOYON 19 Report Date: 2/5/2017 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-20 Development 14.73 16.0 0.00 12,303.0 12,303.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 1/21/2017 1/22/2017 44.13 43.13 1.00 3/5/2017 Last Casing String INTERMEDIATE, 12,290.5ftKB Ops and Depth @ Morning Report 24hr Forecast Laying down 5"DP,SIMOPS-Flush and FP annulus. Lay down 5"DP,SIMOPS annular LOT,flush and FP.Change out Upper rams to 3-1/2"x6"VBR's.Pull wear ring,set test plug.Test BOPE with 4"and 4W TJ.AOGCC notified 2/5 am.M/U BHA#3. Last 24hr Summary Continue P/U and run casing to 12,253'MD,M/U hanger and landing joint.Land at 12,290'MD.C&C for cement,perform 2 stage cement job.Rig down,pull thin wear ring,set and test packoff.R/U and run baseline caliper log from 3,000'MD to surface.R/U to L/D 5"DP. General Remarks Weather Head Count No AIS. Rig and Camp on highline power.Daily cost includes 7-5/8"casing and cement. Overcast,-8°F,Wind calm,Vis 10 m 52.0 Supervisor _ .. Title Ken Harding Rig Supervisor Rob Reinhardt Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Hanna Sylte Completions Engineer Time Log - Time P Start Time End Time Dur(hr) Phase Op Code', Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE) Operation 00:00 03:30 3.50 INTRM1 CASING PUTB P 10,638.0 12,253.0 Continue P/U and run 7-5/8" 29.7#L-80 H563 Dopeless casing from 10,638'MD to 12,253'MD total 304 joints in the hole. 03:30 03:45 0.25 INTRM1 CASING HOSO P 12,253.0 12,290.0 M/U hanger and landing joint, land casing @ 12,290.5'MD. Total 304 joints in the hole,69 Centek centralizers,27 Solid body centralizers.S/0=155-120k. 03:45 09:00 5.25 INTRM1 CEMENT CIRC P 12,290.0 12,290.0 Establish circulation,stage up from.5 bpm to 8 bpm,300-420 psi.Attempt to reciprocate string several times up to 420k P/U no movement. SIMOPS-R/D 7-5.8"casing elevators,bail extensions,350T spider slips,clean and clear rig floor.Lay down 5"subs and equipment,P/U 4"subs.Prep 1502 equipment for cement job. Pre-PJSM on cementing. 09:00 09:15 0.25 INTRM1 CEMENT RURD P 12,290.0 12,290.0 Shut down pump,blow down top drive,R/U 1502 equipment for cement job. 09:15 10:15 1.00 INTRM1 CEMENT CIRC P 12,290.0 12,290.0 Circulate through cement lines @ 8 bpm,670 psi. SIMOPS-PJSM on cementing with DDI,CPAI,SLB,HES. Latest BOP Test Data Date ; Com 1/26/2017 "Test ROPF w/5""test ioint Annular HCR choke/kill 250/2500 nsi for 5 min Unner 3 1/2""X 6""VRR's choke valves 1 12 13 14 aut Page 1/3 Report Printed: 9/25/2017 • Security Level: AK Development }kijj Daily Drilling Report (No Costs 01,4 OW Nat CD5-20 ConoeoF'hilli Report Number: 16 Rig: DOYON 19 Report Date: 2/5/2017 Time Log Tme P State Time End Time Our(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKe) End Depth(EKE) Operation 10:15 12:30 2.25 INTRM1 CEMENT CMNT P 12,290.0 12,290.0 SLB pressure test lines to 4000 psi-good.Bleed off pressure. SLB pumped 40 bbl 12.5 ppg MudPush II @ 4.5 bpm,350 psi. Drop bottom(bypass)plug. Follow with 102.9 bbl 15.8 ppg Qannik Slurry cement @ 4.1-5.5 bpm,310 psi.Load top(shutoff) plug,SLB kick out plug with 20 bbl water.Rig displace with 10.8 ppg LSND @ 8 bpm FCP 300- 580 psi,slowing to 3 bpm as plugs pass the stage collar. Observed some packing off @ —5000 stks,reduce rate to 3 bpm, pressure and returns stabilized. Bump plug on strokes @ 5402 FCP 510 psi.Pressure up to 1030 psi and hold 5 min,bleed off and check floats-good.CIP @ 12:28 hrs. 12:30 14:00 1.50 INTRM1 CEMENT CIRC P 12,290.0 7,745.0 Pressure up on casing to 3250 psi and observe stage tool open (7,744.91'MD) Stage pumps up to 8 bpm,500 psi.Circulate and condition mud for stage 2 cement job,total pumped 610 bbl. SIMOPS-PJSM on stage 2 cement. 14:00 16:00 2.00 INTRM1 CEMENT CMNT P 7,745.0 0.0 Pump second stage per plan. SLB pumped 40 bbl 12.5 ppg MudPush II @ 3.8 bpm 240 psi, followed by 61.1 bbl 15.8 ppg Qannik slurry cement @ 3.8-4 bpm,200 psi.Load top(Closing) plug,SLB kick out with 20 bbl water @ 5.5 bpm, 149 psi.Rig displace cement with 10.8 ppg LSND @ 8 bpm,300-630 psi. Reduce rate to 3 bpm 330 psi @ 3242 strokes,Bump plug on strokes @ 3365,FCP=380 psi. Pressure up to 1340 psi and observe stage tool shift closed. Continue to increase pressure to 2500 psi and hold for 5 minutes. Bleed off pressure and check for flow-no flow.Stage tool closed. CIP=15:36 hrs. 16:00 17:30 1.50 INTRM1 CEMENT RURD P 0.0 0.0 Blow down and rig down casing tools and equipment,lay down landing joint.FMC pull thin wall wear ring. 17:30 18:30 1.00 INTRM1 CEMENT WWSP P 0.0 0.0 Set 7-5/8"packoff,pressure test to 5000 psi for 10 minutes CPAI witnessed,good.Set 7-1/4"ID wear ring. Page 2/3 Report Printed: 9/25/2017 Security Level: AK Development • Daily Drilling Report (No Costs CD5-20 Report Number: 16 ConocoPhitlips Rig: DOYON 19 Report Date: 2/5/2017 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code T X Trbl Code Trbl Class. Start Depth(ftKB) • End Depth(ftKB) Operation 18:30 00:00 5.50 INTRM1 EVALWB ELOG P PJSM,R/U E-line tools and equipment,calibrate tools on rig floor.RIH with 40 arm caliper and log from 3,000'MD E-line measurement to surface.Rig down E-Line equipment. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Com Type Depth(ftKB) Dens(Ib/gal) Via(s/qt) PVCalc(cP) (bf/10Off') (lbf/100ftF) (Ibf/100ftl (Ibf/100ft2) MBT(Ibibbl) (mL/30min) pH (F) (%) Low Solids 12,303.0 10.80 51 15.0 22.0 8.0 12.0 16.007 22.0 6.3 9.4 69.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 45 15.0 24.0 9.0 13.0 18.007 22.0 6.1 9.7 78.0 • 12.5 Non- Dispersed Low Solids 12,303.0 10.80 45 15.0 23.0 9.0 13.0 17.007 24.0 6.0 9.8 81.0 12.5 Non- Dispersed Low Solids 12,303.0 10.80 49 16.0 24.0 10.0 15.0 20.008 28.0 6.1 9.5 80.0 12.5 Non- Dispersed Injection Fluid Fluid Source From Lease(bbl). `, Dest +; Vendor Manifest Number j Note Water Based Mud CD5-20 275.0 CD1-01 AES 477098 Water Based Mud CD5-20 275.0 CD1-01 AES 477099 Wellbores Wellbore Name Wellbore API/UWI CD5-20 501032075200 , Section Des • Size(in) Act Top(ftKB) . • Act Btm.(ftKB) ;r Start Date End Date CONDI 24 36.5 115.0 3/5/2016 3/5/2016 SURFAC 13 1/2 115.0 2,357.7 1/22/2017 1/26/2017 INTRM1 11 2,357.7 12,303.0 1/26/2017 2/8/2017 PROD1 6 3/4 12,303.0 24,119.0 2/8/2017 2/20/2017 Casing Strings Csg Des Run Date OD(in) Wt/Len(Ib/ft) Grade ;Set Depth(ftKB) ' Com INTERMEDIATE 2/5/2017 7 5/8 29.70 L80 12,290.5 7-5/8"29.7#BTCM/H563 dopeless.Total Centek=69,Total Solid body cent=27.5/0=155k. Cement Intermediate Casing Cement -Started @ 2/5/2017 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-20 INTERMEDIATE, 12,290.5ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 11,717.0 12,290.5 8 480.0 Fluid ,-: Class,', Amount(sacks) Vol Pumped(bbl) Dens:(Ib/gal) Yield(ft'/sack) Est Top(ftKB) iEstBtm(ftKB) Intermediate Cement G 496 102.9 15.80 1.16 11,171.0 12,303.0 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Casing Cement 6,834.0 7,745.0 8 360.0 Fluid • - Class Amount(sacks). Vol Pumped(bbl) Dens(Ib/gal) Yield(ft/sack) Est Top(ftKB) Eat Btm(ftKB) Intermediate Cement G 295 61.1 15.80 1.16 6,834.0 7,745.0 Page 3/3 Report Printed: 9/25/2017 . r.- --- N-- r- r- r- r- r- r- r- r- r- r- r- r- r- r- r- r- r-1,41 COO CC) fia CD - 00f) u) 4) CD CD CD CO N O O O 0 0 0 0 0 0 0 0 CA .7Ic Q d R-° coL O 4) O O O O O O O O O O 0 0 0 0 0 0 0 0 0 0 �M (6 Q' E r Cl) c 0 c' LU 0 1.0 O V) O C 0 LU O LU 0 LU 0 0 U 0 LU 0 > _d x a C OOO NNM M -i Cn uiOOr OOOOCACAO m — E E m a)CD 1 7 dLg)CD `� 0000 0000 0ua0 0 LU COOM0 Md' 000 N I- M 0 M U) :D Oe T . NNM V u) LUCO I` ti 0) 0113 r- N M ,r u) Cfl r` M 0) O 7- N M= j-// r'A > IL JI C 0O Y .0 N N ,; A01' 1 t1) CON NCD CO NtNO CT N- CfltoMN-V- CD CD '53CO7r V N � CD CCCCCCCCW N CO CO CO CO CO CO M CO CO CO CO CO CO CO CO CO CO N N •c O' a) 14,E c - O C C) CD 0 0 0 CD CD 0 0 CD CD CD 0 CD 0 0 0 0 0 CD 0 � V) C CD N Ci) CD CC) CD CC) CD CC) CD CC) CD LC) CD CC) CD CC) O CC) CD CC) O a •L O• O• O NN• M M:'� V LC) COCOrN00oOO) 0) O CO E E m m - 3 n- = r co I,- Cfl Nt N� Nt CC) 00 CO CA CO UD N- N Co N v CO Cfl a0 N N— M v- C) M N c- If) CO r- CC) CO CO N CO Co CO CD N ' - CO CO O ,- c- — CD CD CD O) 0) CO CX) N E5 O P. 0)- r — — r- N NNN co co MMMrt ,t V' V' 'Ct 'ItMMMCOCO U .0. c 7 c Q- la)Ca c N •co O_ o," E 0. !) i , r 'Ct d• 00 N CO CO CO OO N CO CO ,CO N CO O 7f CO N CO N CO N CO / 0 7 O N ' a a - O d• � inLC) Co Co1— NN— W COC'3) CArOO � ,- � NNMMr > a Ca r T r T r r r T X n Y N C Q. d R E m E m m �I N . c OTNCO NtCC) CON� COC CD (0 OCV NO - O _N )) c y C.: CNO c N a) -0 C � ' • E m U i °'E E E TD IL) C0 > Irii m H € (1), ► _ 0 WC C .. T �' LL r c0 --M N a) i .Y o .c 6 d f/1 CO o N I t+ co +' N0. ✓� N C M ---- a) V1 �I Q C Q N r a (/� °' c 0 d co H .E 4" C 1 (/) ,,M.• ,_ .._ ' H Z J 3 " 0) a o _ c c M N .— 0 Q .Q c L1J L 0o N E E y N f_ O O 4- T ro Ci) Z d a L " coN + W — a To' W 0U o > c `°c7) E coM CL a I— a) j tt I— oo a wI I- COC m L 15L C. o T X I I H LQ Cb N LL c T , O Q) g pN O > Y Q Ce w Q , cC 0) yLL o N co E v) C a E Uo vo r � Ern ) TO ° co ma, CO o cCO F-LO O .N .N t p m — >.. C6 C6 O) E i O Cl) c a, o .Co o 'U) ' E0) O "~ ► p a� LL m 03,0 o '� � N . :r+ d U37 0 7 ,� '� ~ H c U co O 3 I a J li '' < a) C:) m 1 2 co o o L —1 0 — N c7 0 0 a) U c - o � � 22 .D = O E.' ca a c D aa)) EI M c N a) -0 0) c > U r- Cn >, a ' c _c c U'2 I— * Lo caQ � =,. U � ayiX � � � � :: -, ; Cement Detail Report CD5-20 C€nacoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/21/2017 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/5/2017 10:15 2/5/2017 16:00 CD5-20 Comment Cement Stages ,44k: Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement casing and TOC 11,717.0 12,290.5 No Yes Yes Cement to 11,171'MD Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 8 8 480.0 510.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 3/4 Comment Cement Fluids&Additives Fluid e .„04; Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 11,171.0 12,303.0 496 G 102.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 124.0 5.75 ' Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Stage#2 1'4,114 � . Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Isolate Sub 97 formation, 6,834.0 7,745.0 No Yes No Cement TOC 6,834' Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 8 8 360.0 380.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 3/4 Comment Cement Fluids&Additives .I,' �... r 0... s � Fluid >e •' '' ert .,.,, Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,834.0 7,745.0 295 G 61.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 138.0 5.25 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 1/1 Report Printed: 9/25/2017 SG.L.Alvord • RECEIVED Alaska Drilling Manager Drilling&Wells JUL 2U11 P.O. Box 100360 2 6Anchorage,AK 99510-0360 ConocoPhilhps Phone: 907-265-6120 July 25, 2017 Liz Link Alaska Oil and Gas Conservation Commission ` I 333 West 7th Avenue, Suite 100 .i5 Li- Anchorage, Alaska 99501 Re: Annular Disposal Report, Second Quarter, 2017 Liz Link: Please find attached the corrected second quarter 2017 annular disposal report for CD5-03. Please call Chip Alvord at 265-6120 or Troyce Allen at 263-4680 should you have any questions. Sincer ly, G. L. Alvord Alaska Drilling Manager SCANNED AUG 0 7 2011 • 1 LO • 0 Z o O L Cr L 0 - X O a O N Z. ri LOT- a � o (7) U M CD O O LO w a N co ._- v ' 0 O O C' NE U N w .z o '') v cc;') o -0 v) 06 O — i 1*-- co O m U 0 CD : o _ CD _ 3 N V 00 4) � C r ONa N > LO (0 to O L. O it 0 o Q 0 d i0 N n Ce-) N U o Z U a c0 cv O > a N- h m a = O U 8 N Q N C a `r) .-- Z i O .c a S a.) ❑ CO CN�O d O •h co a Z N - 0 o E co �) r w ti► a) Z O• ci m 0 N i 0 0 0 O J o N ❑ N O O N .c CA Q E Z Z -a0.c z EN aCr G O d ¢ LLL m , Q C) c co � co of m O QC' vO O a o m v p a, o CO Z 0 > Q N f6 J a a� y co d. a) a' a as Co -o rn 1--- .4- @ w Q . ❑ p 0 co aa) ti O O j�❑ W col-LI = w 0 E LU O 1, Z rt z OZ Z ❑ N c•) 5 0 O 9 a a) U) W U Q Q ❑ �' ❑ \r��, o 1-- < CI) • 0 a) ▪ _ c n U O O o U y cD (� O U) 0 zz CO u_Ni c — H = OC O a E 2 O a) ❑ U o E coin a) Z ZQ a) ch o 0 cc 0 N ami Q U17; yr O O O 00 aai d J I.f. iii ❑ E N m cF. IX m c Cfl t N U U o I— O C3 0 W ? M Qv ❑ ci 111co N Nii 'LQ N V V a1 E N o ti 111 _E . a) Q N f0 ~ co (a - a) > O L c my in 0 CO CO N .TrJ O LL c 3 o a v 'u) i) v 0 6 o 0 N O C.) m d1,- 0 0 w ca Q EvaE a v id c a) N 0 0) H c 0 N a) O C C. . 2 O O U C �'. c c .0 r_ d /3 C CO ¢ c V a (a a 7 0ct, C fl yCO 17) r ••O' Y O 0 U 3 N C E c 3 0) I-- O ❑ O O O coen co MO a) co V lc O (M 0 cc 't CO0 _ -0 N N ¢ o o c y c v CO CD MO d c > w O c E N O CO m to o a) 0 o ❑ v ui c' E w c� N co o X o- �.. re L co O ^_ C N Ea C O N ueL a) W ¢ w N oo O 0 L aa) •— S c v ❑ a`) c ••• o O d N O O 0 .0 = CO CO L a) •• a" E c v r a) O O w i c a) N Z E O U 0 Y Q uy u. V) c 'O L t of O o _3 .0 O 0 -0 .0 .O� co O a N C E in a) N 0 C 0ca. p¢ U N N n n n n F c o a ¢ N d `° o 0 0 o w �- • o L Co a N M $ N N N N 13 • • G.L.Alvord Alaska Drilling Manager Drilling&Wells RECEIVED P.O.Box 100360 V Anchorage,AK 99510-0360 conocoPhillips JUL 13 Z017 Phone: 907-265-6120 AOGGC July 11, 2017 / Liz Link t Alaska Oil and Gas Conservation Commission fit. 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Report, Second Quarter, 2017 Liz Link: Please find attached the second quarter 2017 annular disposal for the Alpine wells. This report shows the volumes disposed into surface casing by production casing annuli during the second quarter of 2017, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2017. Please call Chip Alvord at 265-6120 or Troyce Allen at 263-4680 should you have any questions. Sincerely, t. ak_ G. L. Alvord Alaska Drilling Manager SCANNED JUL2 02017 • i. 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G.L.Alvord Alaska Drilling Manager RECEIVEDDrilling&Wells P.O.Box 100360 JAN 1 9 201/7 Anchorage,K 96120.0360 ConocoPhillips AOGCC January 9, 2017 Liz Link t`" "� Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 �ED q 0 i fi,,r S Re: Annular Disposal Report, Fourth Quarter, 2016 Liz Link: Please find attached the fourth quarter 2016 annular disposal for the Alpine wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2016, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2016. Please call Chip Alvord at 265-6120 or Troyce Allen at 263-4680 should you have any questions. Sincerely, r r G. L. Alvord Alaska Drilling Manager RBDMS ! 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N N V7 7 (� L_ 7 O to y..I H • Oo c w 0 ca a� W >,,,\ ai Cuai a Q Ai v v in Cuas ❑ N E N 0 E N 0 c_ a Ta 3 = > H m c ca al O O 2 O LL = c0 0 °O COCO O o '� N - o a co .0 as 0 'Cr 2 0 CuN O N '_0 d0 Q Q ID L^w Cl) C 2 Cu 02 Cu .O0 a7 C V C m a U ._`. U 7 — O O V7 U C • Q c 13 a? 5 a d c as Cu co• co m 0.g. E— CO3E ❑ c' `r pp 7 0 C7 C ED_ N Q o `0 cm c oiii Cu co CO O O O CO a) c m 0 N n x = y E N fa 0 m aa) ❑ -o ci E w 0 N w a s � d CO 0 -- C a) C 0 C N Q W 0 M CC " E :o Tv 0 r N OC d a) O 2 O a) v` w N m t .. ,r : O 0 N_ f4 U N U ui h C 'O L U O Cl) o U 7 z O a1 -O t Cu p 0 a N . v m c E .. 0 E d co a) O 0. Q �? c /12 ca c0 co co co F c o a Q .0 0 c •c _ 0) a m o 0 0 o W > ` t d N M Q N N N N N a — • • ConocoPhillips RECEIVED Alaska NOV 1. 0 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 30, 2016 ,........-...... .r..�........,. Commissioner Cathy Foerster Alaska Oil & Gas Comm ��r Commission SEED A? 333 West 7thAvenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU).Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor,engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped October 29th 2016. The corrosion inhibitor/sealant was pumped on October 30th 2016. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call Aaron Applehans or Roger Winter at 907-659-7506,if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor 4110 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 10/30/2016 CD5 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD5-01 50103207360000 2160220 1.33' .17 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-02 50103207370100 2160680 1' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 D5-03 50103207180000 2151460 1.08' .1 bbl 66' 10/29/2016 5 gal 10/30/2016 CD5 04 50103207110000 2150720 .875' .07 bbl 66' 10/29/2016 5.1 gal 10/30/2016 CD5-05 50103207120000 2150730 2.25' NA 2.25' 5/29/2016 18 gal 10/30/2016 CD5-07 50103207340000 2160040 1.42' .2 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-08 50103207410000 2160510 4.75' .71 bbl 1.83 10/29/2016 CD5-12 50103207420000 2160520 2.58' .47 bbl 0.66 10/29/2016 5 gal 10/30/2016 CD5-315 50103207160000 2151370 1' .1 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-21 50103207380000 2160310 .75' .6bbl 0.66 10/29/2016 3.4 gal 10/30/2016 • i N m � y Wco O L a' i N -5- = isi -t z 4.... a- 0 T) CO C - O U CO c a) O a) c4 N E 2 N w 4) % 0 CO coCD '0 U) 0 _ w c 0O (n L. 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Z > > O O Z Z Elco cn o N 45 O O O O > c Z Lu U Z ❑ • O 0 Q Q < rn ❑ a rn U c m c D O• F- 0 0 E N E 89 m CO L� o O < r ami r' VO O O O a) ai ui 7 E tL� N cu) 'Cr (n 0 N H J_ v; = s = o �' m c M w 'Q � 3 O O U (n ❑ z O a O N n 2 c a Wco N Q a v con E N o Q ❑ _ :? i- w m m c 3 ui I- a) m 3 = m > O c 0)-o y O O O E --I o it c 3 O COO CO 0 w * i� 12 co a a) 0 N N- N E d m cv d a 0 < Q ❑ v Eo c C7 ai a m m O) c a a7 N El O CO CO c 0 a) o 11 {d a_ C a7 a) V +- %,1 U U C = a yr C Y N L Q c I V C c a w a) •a w m rn c O.G= a3 ❑ c �J, O • Y c Uco co 0 o •c E c 3 M co CO O fn m CNI co o a) uoi c U is m O CO Or 0 CO d c o N co O c v 3 E ai • N o. N O a) a) = o = ❑ -0v; Eo0 N CO x o_ c L CO O .. C' 0 Cl vi C G., o w CO Q O ("N O 0 — E = a >,a p 6 a a o O c ui as c '� c a c N ' c a a) o � 0 c) a m m c cc p N v m O .. 0 cn .. .O cc U •. Z a7 O O a) U N U 7 a N CO V 01 a) .. N E Q. O O u_ a) -- • O a w0 c E M O a) c c a -o U :c o � N m m m co 12 E • Q CC o m rn W m a O N Vi a 0 N N N N > v r- .- o - • 411 OF T� A te,THE STATE Alaska Oil and Gas of TT /e� c Conservation Commission 333 West Seventh Avenue '' /.., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " -..,' Main: 907.279.1433 OFA" 41088' Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 SCANNED c\BA. kN 2 °u , Anchorage, AK 99510 Re: Colville River Field, CRU CD5-03 Permit to Drill Number: 215-146 Sundry Number: 316-469 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. oerster Chair DATED this day of October, 2016. RBDMS '-'OCT 1 0 2016 LiSTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 20 /oG l 075?S f � ANNULAR DISPOSAL APPLICATION AOGCC 20 AAC 25.080 1.Operator 3. Permit to Drill Name: 215-146 _ ConocoPhillips Alaska 4.API Number: 50-103-20718-00-00 • 2.Address: 5.Well P.O.Box 100360,Anchorage,Alaska C(tU CD5-03 6.Field: Colville River Unit- Alpine Pool 7.Publicly recorded wells 8.Stratigraphic description: a)All wells within one-quarter mile: a)Interval exposed to open annulus: CD5-03, CD5-04, CD5-05, CD5-313, CD5-313PB1, CD5-07, CD5-09, CD5-10, CD5-314, CD5-315, CD5-315PB1, CD5-01, Torok and Seabee formation,shale,siltstone and sandstone CD5-02, CD5-21, CD5-08, C5D-12 and CD5-06 b)Waste receiving zone: b)water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9.Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,342' MD and 1,320'TVD None 11. Previous volume disposed in annulus and date: 12.Estimated slurry density: 13.Maximum anticipated pressure at shoe: 25,374 as of 9/14/2016 densities range from diesel to 12#/gal 1929 14. Estimated volume to be disposed with this request: 15.Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud,drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids,diesel,formation fluids associated with the 16.Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 15-Oct-16 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17.Attachments: Well Schematic(Include MD and TVD) ECement Bond Log(if required) ❑ FIT Records w/LOT Graph E Surf.Casing Cementing Data E Other ❑✓ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Title: it 0 Printed Phone Name: Chip Alvord Number: 265-6120 Date: 1( k4(I G Commission Use Only Conditions of approval: LOT review and approval: C"th// Subsequent form required: 10 Approval number: _ `-Q APPROVED BY RBDMS I,z OCT 1 0 2016 Approved by: ) / COMMISSIONER THE COMMISSION Date:/ _6 Form 10-40 D 'ev. 42004 CIONS ON REVERSE unit in Duplicate 9//NiS' YTLa////4RI GIN GDS✓ 4�27�.Zo�� %//,d • 411 Annulus Disposal Transmittal Form - Well CD5-03 AOGCC Regulations,20 AAC 25.080(b) 1 Designation of the well or wells to receive drilling wastes: CD5-03 2 The depth to the base of freshwater aquifers and permafrost,if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost= 1320' TVD(RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref.AOGCC Conservation Order No.443, March 15. 19991 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud,drilling cuttings,reserve disposed of and the estimated density of the waste slurry. pit fluids,cement-contaminated drilling mud,completion fluids,diesel,formation fluids associated with the act of drilling a well,drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings,and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be Humped is 70.000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate,mud plant rinse fluid generated by rinsing waste under(h)(3)of this section. tanks and equipement after producing drilling/completion fluid(see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1929 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports,LOT/FIT reports and base of any freshwater aquifer and permafrost,if present,and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the The top of cement is 6877'MD in the intermediate casing depth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this depth 12 The duration of the disposal operation,not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and,if so,a summary of the dates of the disposal operations,the volumes of waste disposed of,and the wells where the drilling waste was generated. 14 The well(s)where the drilling waste to be disposed of was or CD5-99,CD5-17,CD5-18,CD5-20,CD5-19,CD5-314X, will be generated. and CD5-316 along with future planned wells on CD5 15 If the operator proposes not to comply with a limitation N/A established in(d)of this section,an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • ConocoPhillips Alaska,Inc. r Post Office Box 100360 • • Anchorage,Alaska 99510-0360 ConocoPh i I l i ps Telephone 907-276-1215 September 14, 2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-03 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD5-03 (sundry permit#315- 762) be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD5, it}'s requested that the volume limit described in 20-ACC 25.080 d. 1.be increased from 35,000 bbl.to 70,000 bbl. ✓ The other wells not yet permitted for annular disposal are either in too close a proximity to exploration wells or are not good annular disposal candidates. This leaves us with the choice of re-permitting a previously used annular disposal well to increase the allowable injection volume. Of the wells on the CD5 pad previously used for annular disposal,CD5-03 is a strong candidate for increasing the allowable injection volume. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. CD5-03 was last used for annular disposal on August 24, 2016 after injecting a total volume of 25374 bbls. Increasing the allowable disposal volume for CD5-03 will allow for time to drill more wells and potentially other candidates for annular disposal. For further details,please reference the annular disposal permit for CD5-03, approved on January 8,2016. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD5-03. Additional information regarding wells within '/4 mile radius that have not previously been submitted to the AOGCC are included.Also attached is the updated annular disposal transmittal form. If you have any questions or require further information, please contact Nina Anderson at 263-6403 or Chip Alvord can also be reached by calling 265-6120. Sincerely, l ;( i/7 bNina Andon Drilling Engineer cc: CD5-03 Well File Chip Alvord ATO-1570 i 0 ......,7I u Oi OON x— ZW �0;o 'n N. \ I ` E 0 en ‘11111111 IX LO 41111111111 to W daOm Mt O M U) wro ZU ----N M (Wo O1O ..7111111 ) Lo M CDO •— 0 LO CD O L. U CU Co 1 o 0 0 N ILUO LO IOU)O UoSO ) nO )uoN/ - u�; 0N CD x_(u / isn 055) (+OA' (N �� X 6 E 0 - 3-0 / 1 2' E E m m. Z5 000. ,i a a' zzz / r ..' 04. 3I- am) DIg" e -O a a C J N O. a re _ W ' M O'.. 0 d. N M.2E/8 0 C0)00 C O a 6 . ,,,J6 O VCO (0 `3'6 (O V' C') a J o A 0 MO' (0r0 0 N- 0OO)y0N- O 'M O(i3 0 W O .• O E`• aD 0 Ol '' v O F '"N N.N. 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N C E y V`— V'4 N MON-N-4?N 'ki''.d'` o1 O0 2, N y � s3 ' r m tai U CD ; w O re 0 LL O 11 0 N N Z X n C N O co co W U a` , co �' m WF aa- O O O O N I O d ,Ln 4'1 t0 11; � O N 00 mo '� 0 3 ,TU U U Q O V M O N N O } Z --0,40.. �, ¢' Q (n 1n (0 l0 /'J, X O (/� d DOD O 0 m n Q O `-000,00 h w y CC CD c a V m s m W 2 0 0 0 0 (ri •N N N - H _, - 7 C) m m 0 c a U N m LL�/ U m E o LL d y m C 44 r.4 • D% N Un CNy N N Q 0 4„, _ d M M 0 C w N N(O \ N O . ' a U }Y"} >- } } } .m } . ..Ix / o OC Q) U L -73 mz1',tt3(0 MO r NT-MNO n 0O '-' m wMO0O , 00 OOOOFA0 d00• O 0M (0 10.10(0i (0 (0 (0 Um o N 00 .'0 0O 0 0000000 (43 J t, U U U0 0ø0O000()0( 0 -00 z J • • Cement Detail Report ® • CD5-06 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL,7/11/2016 15:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 7/14/2016 05:00 7/14/2016 07:45 CD5-06 Comment Dowell PT lines 2500 psi(good). Pump w/6 bpm @ 500-600 psi=75.3 bbls 10.5 ppg mud push,drop bottom plug,310 bbls 11.0 ppg 1.91 ft3/sk yld DeepCRETE lead cmnt,58.2 bbls 15.8 ppg 1.16 ft3/sk yld class G tail cmnt,drop top plug,20.1 bbls H2O. Rig displace 192.6 bbls(1920 stks) 10.0 ppg spud mud w/ICP 8 bpm @ 700-980 psi&FCP 3.5 bpm @ 550 psi. Bump plug&pressure up to 1100 psi for 5 min.Check floats(good)full returns w/231 bbls good cmnt to surface, reciprocate pipe 30'. CIP @ 7:30 hrs. Flush stack w/black water&function annular 3 times. Shut in annular&monitor psi. Cement Stages 1'; Stage#1 ;.. Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 36.8 2,293.3 Yes 231.0 Yes Yes Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 4 6 550.0 1,100.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives I Fluid "3 Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.8 1,804.0 842 DeepCRETE 310.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 0.00 11.00 6.00 50.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.5 %BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,804.0 2,293.3 285 G 58.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 0.00 15.80 5.00 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 8/24/2016 • CD5-06 10 3/4"Surface Casing Well: CD5-06 10-3/4", 45.5# L-80 BTC & H d 563 Casin• Date: 7/14/2016 ConocoPhillips Rig: Doyon 19 Alaska,Inc, Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 36.73 FMC 10-3/4" Casing Hanger .18 36.73 10-3/4", 45.5#, L-80, HYD563 Casing Pup, pin x pin 2.23 36.91 Jts 16 to 56 41 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 1617.22 39.14 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt 9.81 1656.36 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt 9.35 1666.17 Jts 5 to 15 11 Jts 10-3/4", 45.5#, L-80, HYD563 Dopeless Casing 451.95 1675.52 Jts 4 to 4 1 Jts 10-3/4", 45.5#, L-80, BTC pin X HYD563 box Casing XO Jt 42.56 2127.47 Jts 3 to 3 1 Jts 10-3/4", 45.5#, L-80, BTC Casing 40.60 2170.03 10-3/4" HES Float Collar 1.19 2210.63 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC Casing 78.75 2211.82 10-3/4" HES Composite Shoe 2.72 2290.57 2293.29 2293.29 2293.29 2293.29 2293.29 2293.29 10-3/4" Shoe at 2,293' MD /2,190' TVD 2293.29 13-1/2" TD at 2,313' MD /2,198' TVD, 10' rathole 2293.29 2293.29 2293.29 2293.29 1 Centek 10' up from shoe w/stop rings on Jt#1 2293.29 1 Centek 30' up from pin w/stop rings on Jt#2 2293.29 1 Centek 20' up from pin w/stop rings on Jt#3 2293.29 1 Centek every joint from #4 to #14 Floating 2293.29 1 Bow spring every Jt from #15 to #54 across collars 2293.29 1 Centek floating on jt#55 2293.29 2293.29 Total Centralizers = 15 Centeks, 40 Bow springs 2293.29 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2293.29 2293.29 2293.29 2293.29 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 170 K MU Tq with Volant- 16.2 k ft/lbs trq for Hyd 563 and 19.2K ft/lbs on dopeless Down Wt 120 K Jts Bakerlocked to pin end of#3 Block Wt 60 K Drifted with 9.885"drift Rig Supervisors:L. Hill/A.Dorr • Security Level: AK Development Daily Drilling Report s / CD5-06 Itlfps% Report Number: 11 ConocaPh Rig: DOYON 19 Report Date: 7/21/2016 Wet Type AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10390885 14,220,000.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-06 ALPINE 9.66 11.0 0.00 9,621.0 9,621.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 5,041.05 365,700.62 627,308.16 4,239,176.99 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 7/11/2016 7/12/2016 38.05 32.49 5.56 8/13/2016 Last Casing String INTERMEDIATE,9,611.8ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE w/4"and 4W test joint,AOGCC waived witness Continue laying down DP,change rams,saver sub.R/U and test BOPE w/4"and 4'/z'TJ,Annular flush and FP. Install wear ring, P/U BHA#4 and RIH w/4"DP. Last 24hr Summary Continue running casing to depth,pick up hanger and landing jt,land @ 9,611.76'.C&C mud for CMT,reduce MW to 10.5 ppg.Cement casing per program. Check floats,FC,set and test packoff...R/D casing and cementing equip. LID 5"DP. Flush and FP annulus @ 8.5 hrs after CMT. General Remarks Weather Head Count No AIS.Camp on high line.Rig on gen power. Partly cloudy,36°F,Wind 5 mph N,WC 34° 52.0 Vis 10m. Supervisor Title Larry Hill Rig Supervisor Rob Reinhardt Rig Supervisor Joseph Engel Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-TX Triol Code T€bi Class (ftKB)', End Depth(ftKB)' Operation 00:00 03:30 3.50 INTRM1 CASING PUTB P 8,599.0 9,573.0 Continue P/U and RIH with 7-5/8" 29.7#L-80 Hydril 563 casing per detail from 8,599'MD to 9,573' MD. 03:30 03:45 0.25 INTRM1 CASING HOSO P 9,573.0 9,611.0 Make up casing hanger and landing joint per FMC,land on hanger @ 9,611'shoe depth, S/0=140k. 03:45 09:00 5.25 INTRM1 CEMENT CIRC P 9,611.0 9,611.0 Establish circulation @.5 bpm, 610 psi.P/U and break over @ 340k.Continue staging up rate to 6 bpm,reciprocating pipe,580- 360 psi,heaviest MW out=11.8+ PPg. SIMOPS-Rig down elevators and bail ext,clean and clear rig floor, Lay down casing tools and equipment via beaver slide.Load pipe shed with additional 129 jts 4" 14#DP.(Total 76 stds 14#and 20 stds 15.7#in shed).Lay down 4 stds 5"DP via mousehole while circulating via Volant. 09:00 09:30 0.50 INTRM1 CEMENT OWFF P 9,611.0 9,611.0 OWFF-static.(SIMOPS-blow down top drive,R/U 1502 cement equipment).P/U and break over casing string @ 320k after rigging up to cement line. Latest BOP Test Data Date Corn 7/15/2016 I BOPE Test.Test with 5"test joint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and needle valve to 250/3 500 Page 1/3 Report Printed: 8/24/2016 • Security Level: AK Development Daily Drilling Report CD5-06 c+ PhiCls Report Number: 11 Ciaitxtwt�R� Rig: DOYON 19 Report Date: 7/21/2016 Time Log Time Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbi Class (ftKB) End Depth(ftKB) Operation 09:30 12:30 3.00 INTRM1 CEMENT CIRC P 9,611.0 9,611.0 Continue circulate and reciprocate via cement hose,stage up rate from 6-8 bpm,cut mud weight from 10.8 ppg to 10.5 ppg.FCP 8 bpm @ 620 psi.P/U=305k, S/0=185k. (SIMOPS-Lay down 16 stands 5" DP via mousehole and tuggers.) 12:30 15:00 2.50 INTRM1 CEMENT CMNT P 9,611.0 9,611.0 SLB pressure test cement lines to 3000 psi-good.SLB pumped 40.1 bbl 12.5 ppg Mud Push,drop bottom plug.Pump 101.3 bbl 15.8 ppg Qannik slurry-3-4 bpm,drop top plug,kick out with 10 bbl water from SLB unit.Rig displaced with 10.5 ppg mud @ 8 bpm 270-830 psi,reduce rate to 3.5 bpm 550 psi @ 420 bbl away.Bump plug @ 430 bbl,4275 stks.Pressure up to 1100 psi and hold for 5 min.CIP @ 14:26 hrs.Checked floats- good.Flow check static. 15:00 15:30 0.50 INTRM1 CEMENT RURD P 9,611.0 9,611.0 R/D and L/D Volant CRT,blow down cment line. 15:30 15:45 0.25 INTRM1 CEMENT RURD P 9,611.0 0.0 Pull and lay down landing joint, drain stack. 15:45 17:00 1.25 INTRM1 CEMENT WWSP P 0.0 0.0 Pull wear ring,set packoff and test to 5000 psi for 10 min witnessed. 17:00 17:45 0.75 INTRM1 CEMENT SVRG P 0.0 0.0 Service top drive and draw works. 17:45 00:00 6.25 INTRM1 CEMENT PULD P 0.0 0.0 Install 5"elevators,L/D 7 stands 5" HWDP and 64 stands 5"DP. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) .Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft°) (Ibf/10Oft9) i(lbf/10Oft2)', (Ibf/10Oft) MOT(lb/bbl) (mL130min) pH' (CF) (%) Low Solids 9,621.0 10.50 42 11.0 21.0 8.0 10.0 11.005 17.5 0.0 9.3 86.0 12.0 Non- Dispersed Low Solids 9,621.0 10.50 38 11.0 20.0 6.0 8.0 9.004 17.5 0.0 9.5 90.0 12.0 Non- Dispersed Low Solids 9,621.0 10.80 39 11.0 21.0 7.0 10.0 11.005 17.5 0.0 9.5 85.0 13.5 Non- Dispersed Low Solids 9,621.0 10.80 51 14.0 27.0 11.0 12.0 15.006 17.5 7.5 9.3 71.0 13.0 Non- Dispersed Injection Fluid Fluid Source From Lease(bbl) Oast Vendor Manifest Number Note Drilling Mud WBM CD5-06 280.0 CD1-01 AES 476545 Drilling Mud WBM CD5-06 260.0 CD1-01 AES 476548 Drilling Mud WBM CD5-06 250.0 CD1-01 AES 476544 Drilling Mud WBM CD5-06 250.0 CD1-01 AES 476546 Page 2/3 Report Printed: 8/24/2016 _tom • Security Level: AK Development Daily Drilling Report CD5-06 ConocoPhillips Report Number: 11 Rig: DOYON 19 Report Date: 7/21/2016 Injection Fluid Fluid Source From Lease(bbl) 'best ; Vendor %, ,ManifestNumbeC ?; Note Drilling Mud WBM CD5-06 250.0 CD1-01 AES 476547 Wellbores + Wellbore Name Wellbore API/UWI CD5-06 501032074400 Section Des Size(in) _ Act Top(ftKB),' Act Btm(ftKB) Start Date End Date CONDI 20 36.5 115.0 3/28/2015 3/28/2015 SURFAC 131/2 115.0 2,303.0 7/12/2016 7/16/2016 INTRM1 11 2,303.0 9,621.0 7/16/2016 7/23/2016 PROD1 6 3/4 9,621.0 18,057.0 7/23/2016 7/27/2016 Casing Strings Csg Des Run Date OD(in) WI/Len(lb/ft) Grade Set Depth(ftKB) Corn INTERMEDIATE 7/21/2016 7 5/8 29.70 L80 9,611.8 P/U=305k,S/0=185k @ 9611'MD Cement Intermediate Casing Cement -Started @ 7/21/2016 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-06 INTERMEDIATE,9,611.8ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 8,470.0 9,621.0 8 550.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(Ib/gal) Yield(t/sack) Est Top(ftKB) :': Est Ben(ftKB) Intermediate Cement G 510 101.3 15.80 1.16 8,470.0 9,621.0 Head Count/Manhours Function Company Name Count ,;;• Note RIG SUPERVISOR ConocoPhillips Company 1 Rob RIG SUPERVISOR SolstenXP 1 Larry COMPANY ENGINEER ConocoPhillips Company 1 Joe SAFETY SolstenXP DRILL CREW Doyon Drilling Inc 26 Doyon Hands CATERING/CAMP Kuukpik Corporation 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 3 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger 1 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Oil Tools OTHER 1 Beacon Site Control SERVICE ENGINEER SolstenXP 1 Kelly MPD WELLSITE GEOLOGIST CASING/TUBING Doyon Drilling Inc 1 OTHER Peak Oilfield Services MWD Gyrodata Inc. WIRELINE Halliburton Energy Services Inc. 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Cement Detail Report CD5-06 ConocoPhillips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 7/21/2016 12:30 7/21/2016 15:00 CD5-06 Comment SLB pressure test cement lines to 3000 psi-good.SLB pumped 40.1 bbl 12.5 ppg Mud Push,drop bottom plug. Pump 101.3 bbl 15.8 ppg Qannik slurry—3-4 bpm,drop top plug,kick out with 10 bbl water from SLB unit.Rig displaced with 10.5 ppg mud @ 8 bpm 270-830 psi,reduce rate to 3.5 bpm 550 psi @ 420 bbl away. Bump plug @ 430 bbl,4275 stks.Pressure up to 1100 psi and hold for 5 min.CIP @ 14:26 hrs.Checked floats-good. Flow check static. Cement Stages Stage# Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 8,470.0 9,621.0 Yes Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 8 7 550.0 1,100.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 9,487.0 Drill Bit 6 3/4 Comment SLB pressure test cement lines to 3000 psi-good.SLB pumped 40.1 bbl 12.5 ppg Mud Push,drop bottom plug. Pump 101.3 bbl 15.8 ppg Qannik slurry—3-4 bpm,drop top plug, kick out with 10 bbl water from SLB unit.Rig displaced with 10.5 ppg mud @ 8 bpm 270-830 psi,reduce rate to 3.5 bpm 550 psi @ 420 bbl away.Bump plug @ 430 bbl,4275 stks.Pressure up to 1100 psi and hold for 5 min.CIP @ 14:26 hrs.Checked floats-good.Flow check static. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement Stage 1 Qannik slurry 8,470.0 9,621.0 510 G 101.3 15.8 ppg Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 0.00 15.80 114.0 5.00 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 _ 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Page 1/1 Report Printed: 8/24/2016 o s : • • Security Level: AK Development Daily Drilling Report tt4,Alms CD5-06 CoriocoPhiiiips Report Number: 4 F3:hsks Rig: DOYON 19 Report Date: 7/14/2016 Well Type';` AFE Typ Network/i6# AFE.Supp Amt(Cost) Development ORIGINAL 10390885 14,220,000.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-06 ALPINE 2.66 4.0 0.00 2,303.0 2,303.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 8,402.49 68,738.15 732,683.43 1,945,674.75 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 7/11/2016 7/12/2016 38.05 36.74 1.31 8/17/2016 Last Casing String SURFACE,2,293.3ftKB Ops and Depth @ Morning Report 24hr Forecast N/U BOPE&MPD equipment. N/U BOPE&MPD equipment.Test BOPE. M/U remaining 9 7/8" BHA&single in hole to drill out. Last 24hr Summary RIH 10 3/4"casing&land on hanger @ 2,293'Circ&cond for cement job.Cement casing. Flush stack&shut in well.W.O.C.SIMOPS-Work on MP2's,Service rig. M/U BHA#3.P/U 5"DP.Open annulus&F/C(static). L/D landing jt&flush stack. N/D surface riser&annular. General Remarks Weather Head Count No AIS.Camp on high line.Rig on gen power @ 17:45 hrs. Clear,75°F,Wind NE 8 mph,Vis 10m 52.0 Supervisor Title — ,', Larry Hill Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log r Time Start Depth Start Time End Time Dur(hr) Phase'. Op Code Activity Code P-T-X TM!Code Trtrl Class (ftKB) End Depth(EKE) Operation 00:00 01:00 1.00 SURFAC CASING PUTB P 2,015.0 2,254.0 PJSM,RIH 10 3/4"45.5#L-80 BTC&Hyd 563 casing f/2,015'to 2,254'(56 jts) 01:00 01:30 0.50 SURFAC CASING HOSO P 2,254.0 2,293.0 M/U hanger&2 part landing joint. Land casing on hanger©2,293' PU wt 170 k,So wt 120 k 01:30 01:45 0.25 SURFAC CEMENT RURD P 2,293.0 2,293.0 B/D top drive. M/U cement lines. R/D bale extensions&elevators. 01:45 04:45 3.00 SURFAC CEMENT CIRC P 2,293.0 2,293.0 Circ&cond mud for cement. Stage pumps up to 8 bpm @ 440 psi.Reciprocate pip w/full returns. SIMOPS-PJSM on cementing. 04:45 05:00 0.25 SURFAC CEMENT OWFF P 2,293.0 2,293.0 F/C(static) 05:00 07:45 2.75 SURFAC CEMENT CMNT P 2,293.0 2,293.0 Dowell PT lines 2500 psi(good). Pump w/6 bpm @ 500-600 psi= 75.3 bbls 10.5 ppg mud push, drop bottom plug,310 bbls 11.0 ppg 1.91 ft3/sk yld DeepCRETE lead cmnt,58.2 bbls 15.8 ppg 1.16 ft3/sk yld class G tail cmnt,drop top plug,20.1 bbls H2O.Rig displace 192.6 bbls(1920 stks) 10.0 ppg spud mud w/ICP 8 bpm @ 700-980 psi&FCP 3.5 bpm @ 550 psi. Bump plug&pressure up to 1100 psi for 5 min.Check floats(good)full returns w/231 bbls good cmnt to surface, reciprocate pipe 30'.CIP©7:30 hrs.Flush stack w/black water& function annular 3 times.Shut in annular&monitor psi. Latest BOP Test Data lDate ;.. Corn '• ' ',/'• Page 1/3 Report Printed: 8/24/2016 • • Security Level: AK Development Daily Drilling Report CD5-06 tPps Report Number: 4 ConocoPhiRig: DOYON 19 Report Date: 7/14/2016 Time Log Time Start Depth Start Time .End Time I Our(hr) Phase Op Code Activity Code P -X 'Ttbt Cod& '. Tfb)Class. (ftKB)', End Depth(ftKB) Operation 07:45 08:30 0.75 SURFAC CEMENT RURD P 0.0 0.0 B/D cement lines&R/D Volant tool.Clean&clear floor. Break out 7'pup jt on landing jt. 08:30 11:15 2.75 SURFAC CEMENT WOC P 0.0 0.0 Service rig.Work on MP 2's.C/O swivel packing.SIMOPS- mobilize BHA tools&equipment to rig floor.SIMOPS-W.O.C.& monitor psi on annulus 60 psi. 11:15 13:45 2.50 SURFAC CEMENT WOC P 0.0 0.0 M/U 9 7/8"intermediate BHA& rack back in derrick.SIMOPS- W.O.C.&monitor psi on annulus 80 psi. 13:45 15:45 2.00 SURFAC CEMENT WOC P 0.0 0.0 Work on MP 2's.C/O skate ram. SIMOPS-W.O.C.&monitor psi on annulus 60 psi. 15:45 16:00 0.25 SURFAC CEMENT WOC P 0.0 0.0 Remove skate roller&prep to P/U 4"DP 16:00 20:15 4.25 SURFAC CEMENT WOC P 0.0 0.0 P/U 123 jts 5"DP&rack back in derrick.SIMOPS-W.O.C.& monitor psi on annulus 37 psi.(@ 19:30 hrs bleed off psi&monitor for psi increase.static) 20:15 00:00 3.75 SURFAC CEMENT NUND P 0.0 0.0 Drain riser. B/D lines.L/D landing jt&mouse hole.N/D riser&L/D. N/D annular&remove from cellar. Mud Check Data YP Calc Gel(10s) <Gel(1Bm)I Gel(30m) HTHP Filtrate Density Temp Solids,Corr.'. Type Depth(ftKB) Dens(Ib/gal) Vis(sfgt) PV Calc(cP) (Ibf/100ft) (lbf/1o0ft') (tbfl[ #'- (Ibff100fP) MST(Ib/bbl) (mL/30min) pH ('F) (%) DRILPLEX 2,303.0 10.00 39 14.0 10.0 3.0 3.0 3.001 11.5 0.0 10.3 8.0 DRILPLEX 2,303.0 10.00 38 14.0 10.0 3.0 3.0 4.002 11.5 0.0 10.3 8.0 DRILPLEX 2,303.0 10.00 39 14.0 10.0 3.0 3.0 4.002 11.5 0.0 10.4 8.0 DRILPLEX 2,303.0 10.00 45 13.0 22.0 28.0 26.0 30.012 12.0 0.0 10.5 8.5 Injection Fluid Fluid Source "From Lease(bbl) pest Vendor Manifest Number Note Drilling Mud WBM CD5-06 275.0 CD1-01 AES 476517 CD5-06 Soruce Well Drilling Mud WBM CD5-06 275.0 CD1-01 AES 476516 CD5-06 Soruce Well Drilling Mud WBM CD5-06 250.0 CD1-01 AES 476515 CD5-06 Soruce Well Drilling Mud WBM CD5-06 180.0 CD1-01 AES 476518 CD5-06 Soruce Well Drilling Mud WBM CD5-06 180.0 CD1-01 AES 476519 CD5-06 Soruce Well Drilling Mud WBM CD5-06 125.0 CD1-01 AES 476514 CD5-06 Soruce Well Drilling Mud WBM CD5-06 95.0 CD1-01 AES 476520 CD5-06 Soruce Well Wellbores Wellbore Name Wellbore API/UWI CD5-06 501032074400 Section Des Size(in) Act Top(111(8) Act Btm(ftKB) Start Date End Date CONDI 20 36.5 115.0 3/28/2015 3/28/2015 SURFAC 131/2 115.0 2,303.0 7/12/2016 7/16/2016 INTRM1 11 2,303.0 9,621.0 7/16/2016 7/23/2016 PROD1 6 3/4 9,621.0 18,057.0 7/23/2016 7/27/2016 Casing Strings Csg Des Run Date OD('it) Wt/i en(lb/ft) Grade Set Depth(ftKB) Com SURFACE 7/14/2016 10 3/4 45.50 L-80 2,293.3 Page 2/3 Report Printed: 8/24/2016 • • Security Level: AK Development Daily Drilling Report CD5-06 illips Report Number: 4 Rig: DOYON 19 Report Date: 7/14/2016 Cement Surface Casing Cement -Started @ 7/14/2016 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-06 SURFACE,2,293.3ftKB Cement Returns to Surface Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.8 2,293.3 4 550.0 Fluid Class Amount(sacks) =\totPuntped(bbl) Detis(IVO) Yield(ft?tsack) Est Top(f{KB) Est Btm(EKE) Lead Cement DeepCRETE 842 310.0 11.00 1.91 36.8 1,804.0 Tail Cement G 285 58.2 15.80 1.16 1,804.0 2,293.3 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company RIG SUPERVISOR SolstenXP 2 Larry/Adam COMPANY ENGINEER ConocoPhillips Company 1 Tom SAFETY SolstenXP DRILL CREW Doyon Drilling Inc 25 Doyon Hands CATERING/CAMP Kuukpik Corporation 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger 1 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Oil Tools OTHER 1 Beacon Site Control SERVICE ENGINEER SolstenXP 1 Jerry MPD WELLSITE GEOLOGIST CASING/TUBING Doyon Drilling Inc 1 OTHER Peak Oilfield Services MWD Gyrodata Inc. 2 2 @ CD1 WIRELINE Halliburton Energy Services Inc. (HES) Page 3/3 Report Printed: 8/24/2016 • • Security Level: AK Development Daily Drilling Report 0,2 .. CD5-06 C©nocc#'Ftillips ,•a. Report Number: 5 Rig: DOYON 19 Report Date: 7/15/2016 Well Type AFE Typ Networkttd# AFE+Supp Amt(Cost) Development ORIGINAL 10390885 14,220,000.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-06 ALPINE 3.66 5.0 20.00 2,303.0 2,323.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 12,258.14 80,996.29 164,795.01 2,110,469.76 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 7/11/2016 7/12/2016 38.05 35.82 2.23 8/16/2016 Last Casing String SURFACE,2,293.3ftKB Ops and Depth @ Morning Report 24hr Forecast Drill Ahead—2,800' Drill 9 7/8"X 11"Intermediate 9,363' Last 24hr Summary N/D surface riser. M/U well head&test. N/U BOPE&MPD equipment.Test BOPE.M/U 9 7/8"BHA#3. RIH to 2,047'.Circ B/U&test casing to 3500 psi.W&R to 2,210'.Drill shoe track f/2,210'to 2,323'.Displace to 9.6 ppg LSND. FIT to 18.0 ppg. General Remarks Weather Head Count No AIS.Camp on high line.Rig on gen power.Tested BOPE&tested gas alarms Cloudy,48°F,Wind W 13 mph,Vis 10m 50.0 Supervisor Title Larry Hill Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Stan Depth Start Time End Time Dur(hr) .Phase Op Code I Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 00:45 0.75 SURFAC CEMENT I NUND P 0.0 0.0 N/D annular&remove from cellar. 00:45 02:30 1.75 SURFAC WHDBOP NUND P 0.0 0.0 N/U Alpine gen II well head&N/U BOPE stack.Test lower well head to 1000 psi.(good) 02:30 05:45 3.25 SURFAC WHDBOP MPDA P 0.0 0.0 N/U Flow box,hole fill&bleeder lines,ketchkan,orbit valves, MPD return lines, RCD clamp&trip nipple.Test MPD equipment to 1500 psi(good) 05:45 07:30 1.75 SURFAC WHDBOP RURD P 0.0 0.0 R/U to test BOPE.Set test plug. Fill stack&choke lines w/H20. R/U test chart 07:30 12:45 5.25 SURFAC WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 5"test joint, Test Annular to 250/2,500 psi for 5 min,Test choke valves#1 -14 and needle valve to 250/3,500 psi for 5 min. HCR Choke and Kill,4" Demco,5"FOSV,dart&needle valves,auto&manual IBOP,HCR choke&kill,3 1/2"X 6"upper& lower VBR's,&blind rams to 250/3500 psi for 5 min. Koomey test; IP=2950 psi,manifold press after close= 1300 psi,200 psi recovery 35 sec,full recovery 189 sec,N2-4 bottle average=2350 psi.Tested gas&pit level alarms. Draw down on man&super choke to 1,100 psi.-Test waived by Matt Herrera of the AOGCC. 12:45 13:30 0.75 SURFAC WHDBOP RURD P 0.0 0.0 R/D testing equipment.B/D lines. FMC pull test plug and set 10"ID wear ring. Latest BOP Test Data dateI Cam 7/15/2016 ROPF Test Test with 5"test joint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and needle valve to 250/3 500 Page 1/3 Report Printed: 8/24/2016 r • Security Level: AK Development F F Daily Drilling Report 43.4 CD5-06 l(llps Report Number: 5 ConocoPh Rig: DOYON 19 Report Date: 7/15/2016 Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbt Class (ftKB)l End Depth(ftKB) Operation 13:30 14:00 0.50 SURFAC CEMENT MPDA P 0.0 0.0 Install split bushing&mobilize RCD bearings to rig floor. 14:00 15:30 1.50 SURFAC CEMENT BHAH P 0.0 827.0 M/U 9 7/8"bit to BHA racked back in derrick.Finish M/U BHA#3 to 827' 15:30 16:30 1.00 SURFAC CEMENT TRIP P 827.0 2,047.0 RIH f/827'to 2,047' 16:30 17:00 0.50 SURFAC CEMENT DHEQ P 2,047.0 2,047.0 Shallow hole test MWD tools& Circ B/U w/675 gpm @ 2290 psi 17:00 17:15 0.25 SURFAC CEMENT RURD P 2,047.0 2,047.0 R/U&test casing. 17:15 18:00 0.75 SURFAC CEMENT PRTS P 2,047.0 2,047.0 Test 3500 psi&chart for 30 min (good) 18:00 18:30 0.50 SURFAC CEMENT RURD P 2,047.0 2,047.0 R/D testing equipment. 18:30 19:30 1.00 SURFAC CEMENT COCF P 2,047.0 2,210.0 W&R f/2,047'to float collar @ 2,210'w/450 gpm, 1100 psi,40 rpm,3 k trq 19:30 22:30 3.00 SURFAC CEMENT DRLG P 2,210.0 2,303.0 Drill shoe track f/2,210'to 2,303' w/350-220 gpm,660-290 psi, 30-40 rpm,4.5-6 k trq. 22:30 23:00 0.50 SURFAC CEMENT DDRL P 2,303.0 2,323.0 Drill 20'new hole f2,303'to 2,323 MD/2,216'TVD,ADT.3 hrs,450 gpm,900 psi,40 rpm,4.5 k trq. Displace to 9.6 ppg LSND on fly 23:00 23:15 0.25 SURFAC CEMENT DISP P 2,323.0 2,233.0 Cont.to displace to 9.6 ppg LSND w/450 gpm,880 psi,40 rpm,4.5 k trq.Rack back 1 stand to 2,233' 23:15 23:30 0.25 SURFAC CEMENT OWFF P 2,233.0 2,233.0 F/C.(slight ooze then static) 23:30 23:45 0.25 SURFAC CEMENT RURD P 2,233.0 2,233.0 R/U head pin&TIW. R/U testing equipment. 23:45 00:00 0.25 SURFAC CEMENT FIT P 2,233.0 2,233.0 FIT to 18.0 ppg 957 psi.for 1.2 bbls pumped Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr.', Type Depth(ftKB) Dens(fb/gal) Vis(s/gt) >PVCalc(cP) (Ibfl100ft') (Ibf/100ft') (Ibf/100ft') (Ibf/lOOft') MBT(Ib/bbl) (mL/30min)- pH ('F) (Y) DRILPLEX 2,303.0 10.00 37 14.0 9.0 3.0 3.0 3.001 11.0 0.0 10.5 54.0 8.0 DRILPLEX 2,303.0 10.00 40 14.0 13.0 6.0 10.0 13.005 11.0 0.0 10.1 65.0 8.0 DRILPLEX 2,303.0 10.00 40 14.0 13.0 7.0 12.0 13.005 11.5 0.0 10.3 67.0 8.0 DRILPLEX 2,303.0 10.00 39 14.0 10.0 3.0 3.0 4.002 11.5 0.0 10.3 65.0 8.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-06 275.0 CD1-01 AES 476521 CD5-06 Soruce Well Drill Strings: BHA No.3 - Steerable I Bit Run No. 3 - 9 718in,MDI616,JM3082 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 2,303.0 9,621.0 1.0312/12/12/12/12/12/12/13/13 1-2-CT-G-X-0-BU-TD 172 Drill String Components Jts Item Des OD(in) ID(in) i Top Conn Sz(in) Top Thread Cum Len(ft) 6 3/4"Powerdrive 9 3/4"Stabilizers 6 3/4 5.160 5 1/2 FH 14.47 PD Reciever sub 7 2.810 5 1/2 FH 20.21 PD Flex Collar 6 3/4 4.000 5 1/2 FH 29.52 6 3/4"Periscope 6.89 2.810 5 1/2 FH 50.52 6 3/4"Telescope 7.89 3.880 4 1/2 IF 78.47 Steel Float Sub(NPFV) 7 2.875 4 1/2 IF 80.82 Page 2/3 Report Printed: 8124/2016 • Security Level: AK Development Daily Drilling Report CD5-06 Ccoisi[lips Report Number: 5 Rig: DOYON 19 Report Date: 7/15/2016 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 9 3/4"NM Stab 6.85 2.875 4 1/2 IF 87.92 7"Pony DC 7 2.875 4 1/2 IF 97.99 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 110.57 Float Sub(NPFV) 7 2.875 4 1/2 IF 113.48 1 7"NMDC Corrosion ring 6.7 2.875 4 1/2 IF 144.26 NM Stabilizer 6.85 2.875 4 1/2 IF 151.45 1 7"NMDC 6.85 2.875 4 1/2 IF 181.92 12 HWDP x12 5 3.000 4 1/2 IF 549.48 1 6 1/4"Combo Jars 6 1/4 2.250 4 1/2 IF 579.17 8 HWDP x8 5 3.000 4 1/2 IF 824.07 281 DP NC-50 5 4.276 4 1/2 IF 9,621.00 Drilling Parameters Flow Rate .3 Duni Cult Tune Sliding (gpm) WOB RPM Pu Str Wt Drill tr StYt,. SO Str WI Start(ftKB) End Depth(ftKB) Cum Depth(ft) (hu)__ Time(hr) (gpm) (1000ibf)- (rpm) SPP(psi) (1000lbf) (1000lbt) (10001bf) Oft Btm Te Drill Tq 2,303.0 2,303.0 2,303.0 2,323.0 20.00 0.30 450 20 40 900.0 '131 118 3.Q 5.5 Wellbores" Wellbore Name Wellbore API/UWI CD5-06 501032074400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) StartDate End Date CONDI 20 36.5 115.0 3/28/2015 3/28/2015 SURFAC 131/2 115.0 2,303.0 7/12/2016 7/16/2016 INTRM1 11 2,303.0 9,621.0 7/16/2016 7/23/2016 PROD1 6 3/4 9,621.0 18,057.0 7/23/2016 7/27/2016 Survey Data MD(tIKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS tit) EW(ft)', DLS(°/100ft) 2,319.08 35.06 12.31 2,210.36 -458.58 554.43 65.94 4.44 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company RIG SUPERVISOR SolstenXP 2 Larry/Adam COMPANY ENGINEER ConocoPhillips Company 1 Tom SAFETY SolstenXP DRILL CREW Doyon Drilling Inc 25 Doyon Hands CATERING/CAMP Kuukpik Corporation 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 3 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger 1 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Oil Tools OTHER 1 Beacon Site Control SERVICE ENGINEER SolstenXP 1 Kelly MPD WELLSITE GEOLOGIST CASING/TUBING Doyon Drilling Inc OTHER Peak Oilfield Services MWD Gyrodata Inc. WIRELINE Halliburton Energy Services Inc. (HES) Page 3/3 Report Printed: 8/24/2016 • • CD5-06_7-5/8"Intermediate casing Well: CD5-06 ConocoP'hillips 7 5/8" 29.7#L80 BTC-M & Hyd 563 Dopeless Casing Date: 7/21/2016 Alaska,Inc, Rig: Doyon 19 Depth Jt Number Numf tWell Equipment Description and Comments Length Tops Page 1 ft:OP RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.30 '75.,e, FMC FMC 7.625" fluted hanger .72 34.30 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.80 35.02 Jts 183 to 238 56 Jts 7-5/8", 29.7#, L-80 H563 Dopeless Casing 2237.93 37.82 7-5/8", 29.7#, L80, H563 Pup Jt 9.92 2275.75 7-5/8", 29.7#, L80, H563 Pup Jt 4.71 2285.67 7-5/8", 29.7#, L80 XO jt , H563 DPLS box X BTC pin 10.03 2290.38 Jts 13 to 182 170 Jts 7-5/8", 29.7#, L80, BTC-M Casing 6782.08 2300.41 7-5/8", 29.7#, L80, BTC-M Casing with RA Tag in Coupling 39.25 9082.49 Jts 10 to 12 3 Jts 7-5/8", 29.7#, L-80 BTCM 119.32 9121.74 Jts 9 to 9 1 Jts 7-5/8", 29.7#, L-80 BTCM Casing Whipstock Jt (No Centralizer) 40.69 Jts 7 to 8 2 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 76.96 9281.75 7-5/8", 29.7#, L-80 BTCM Pup Jt 8.41 9358.71 Jts 4 to 6 3 Jts 7-5/8", 29.7#, L-80 BTC-M Casing 121.78 9367.12 7-5/8" HES Float Collar 1.23 9488.90 Jts 1 to 3 3 Jts 7-5/8", 29.7#, L80, BTC-M Casing 119.00 9490.13 7-5/8" HES Eccentric Nose shoe 2.63 9609.13' 9611.76 Alpine C Top 9,230' MD/ 7,429' TVD 9611.76 9611.76 TD 9-7/8" Hole at' 9,621' MD/7,467 ' TVD (11" Hole to 9,517') 9611.76 Casing Shoe at 9,611' MD/ 7,466' TVD 9611.76 9611.76 1 Centek 10' up from shoe w/stop ring on Jt#1 9611.76 1 Centek 30' up from pin w/stop ring on Jt#2 9611.76 1 Centek on every joint, floating from #3 -#8 & 8.41 pup jt 9611.76 Jts 7 and 8, Stop ring 5' up from pin, Centek below stop. 9611.76 No Centralizer on joint#9 9611.76 3 Centeks per 2 joints from #10 -#28, stops at 27', 13', 0'... per schedule. 9611.76 1 Centek on every other joint from #181, #182, #183 9611.76 Straight Blade Centralizer on every other joint from #185 -#237 9611.76 9611.76 9611.76 Total Centralizers = 64 9611.76 Centeks = 37/Straight blades = 27 9611.76 Remarks: Baker Lock shoe track to pin of joint#4 Up Wt 305 K M/U Tq for 7-5/8" HYD563 DPLS 12,400 ft/lbs Dn Wt 185 K Avg. 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L H L D 0 m c 'y .0)0 7 _rn- m » C v aS c0 N 0 N a) a) ` u) H G I c LL a) V E � � � O i x •W a) C % m N -0 0 d ) f1 t- L -C 0 0 7 � c -- a OI-- I - E O H O fl as O o O LL I C. d V .� 2 ce 0 E cY0 ` i , o ii = Q' m y N J 0 C) 0 0 0 0 0 0 ��„ N >"'I'- N �C V Y W 0 ani o N C)CNI C) o C) 0 Z 0 ii) re a II a) m 321nSS32id 0 I w 0 • ! Note to File CRU CD5-03 (PTD 2151460) September 27, 2016 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well CD5-03 Request ConocoPhillips requests approval to increase disposal of waste fluids from 35,000 barrels to 70,000 barrels within well CRU CD5-03 (CD5-03). The CD5-03 development well was drilled to the Alpine Oil Pool within the Colville River Unit. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-3/4" surface casing shoe is set in this well at -2,087' true vertical depth subsea', near the base of a 450-foot thick claystone and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection of an additional 35,000 barrels of waste will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will lie within a radius of about 157' from the wellbore. 8. If injected wastes reach nearby well CD5-09 or other nearby wells, surface casing and cement will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from CRU CD5-03 and sixteen nearby wells.2 The discussion that follows is based on well logs and mud logs from these wells. An index map is provided in Figure 1,below. The proposed annular disposal injection interval in these wells lies in the Torok and Seabee Formations within Section 7, T11N, R4E, Umiat Meridian, which is about 2-1/2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoes of these wells mainly lie between about 1 Unless otherwise noted,all depths presented herein are expressed as negative integers,which represent feet,true vertical depth below mean sea level(mean low,low water). All thicknesses are expressed as positive integers,which represent true vertical feet.All horizontal distances are expressed as positive integers,which represent feet. 2 CD5-01,CD5-02,CD5-04,CD5-05,CD5-06,CD5-07,CD5-08,CD5-09,CD5-10,CD5-11,CD5-12,CD5-21,CD5-313, CD5-314,CD5-315,and Nuiqsut 1. 0 • CD5-03 Annular Disposal September 27, 2016 Note to File Page 2 of 7 -2,084' and to -2,193', near the base of a 450-foot thick interval that is dominated by claystone and mudstone and is continuous throughout the area. This claystone and mudstone interval within the lower Schrader Bluff Formation will provide upper confinement for fluids disposed in the annulus of the well(see Figure 2,below). The annulus open to the disposal interval extends downward from the surface casing shoe at-2,086' to the top of cement for the 7-5/8"casing string,which is estimated to be-4,137'. The portion of the open annulus that will most likely accept the injected waste is a 120-foot thick interval containing several 1-to 10-foot thick beds of siltstone and sandy siltstone that lie below the surface casing shoe between about-2,253' and -2,426'. The aggregate thickness of these thin,potential receptor beds is about 34'. The siltstone and sandy siltstone beds are separated by thin claystone and mudstone intervals. Beneath the disposal interval are several intervals of claystone and mudstone that are continuous throughout the area. These intervals will provide lower confinement for any injected wastes. I 1. )C„Ooo ? / \-- E00t North -raao ,z000 CD5-03 ` CD5-09 o ,00 6000 \ 7-:' -i-sot*,- To of cement . /70... p �..y x 7000 ..., 6000 CD5-03 Open - 8000 T 7000 500 0 \-./ Annulus - / CD5-01 .. �� "— CD5-OS ,r 1Vs00o ,,\ VA .w � 4 3. 0,. 3....0 S I .00 ma r's,. .1. 4000... '''1100(. �{,E 45,...4",'-‘ Y.?�,t n. 600 4000 Surface casing shoe -~ 3 CDS-04 ` CD5-313 f 0 0.5 mile <a_:-' , . . Figure 1. CD5-03 Index Map (Depth tick-marks shown along well paths are measured depths.) The index map above displays trajectories for all wells drilled from and near the Colville River Unit CD5 Drill Site. The magenta line represents a north-to-south trending cross-section from CD5-03 to CD5-313, see Figure 2. The locations of the surface casing shoes for all well bores are illustrated using green-colored • CD5-03 Annular Disposal September 27, 2016 Note to File Page 3 of 7 triangles. The calculated locations of the tops of cement for production casing strings are indicated by orange-colored half circles. The portions of each well bore that lie between the surface casing shoe and the top of production string cement are all assumed to be filled only with drilling mud, and are therefore possibly open to communication. In CD5-03,the open annulus lies between-2,086' and-4,137',with the most likely waste-disposal interval between-2,250' and-2,380' (see Figure 3). Fifteen wells are currently open to these same strata within the quarter-mile radius area of review. The surface casing shoe of CD5-04 lies about 1,160' from the surface casing shoe of CD5-03. The surface casing shoe of CD5-05 lies about 500' from the surface casing shoe of CD5-03. The surface casing shoe of CD5-09 lies about 268' from the surface casing shoe of CD5-03. Figure 2, below, presents a north-to-south trending structural cross-section view of CD5-03 and nearby wells CD5-04 and CD5-05, which were logged to surface using gamma-ray and resistivity tools. Also included is nearby well CD5-313, which was logged to surface using gamma-ray, resistivity, and porosity tools. Resistivity measurements indicate that the base of permafrost occurs at about -1,200' in the CD5 Drill Site area,which is about 1,050' above the top of the proposed disposal interval. The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas,with minor amounts of ethane,propane,and butane. Mud logs were recorded in only two wells drilled in the vicinity of Drill Site CD5: CD5-313 and CD5-04,which are labeled on the map presented in Figure 1. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells(arbitrarily placed at 20 units of gas on the mud log)were-1,850'and -2,000',respectively. So,the entire proposed annular disposal interval contains methane gas. Unfortunately,oil shows are not recorded on the mud logs obtained in nearby wells CD5-313 and CD5-04, apparently due to the use of oil-base drilling mud. In ARCO's Nuiqsut 1 exploratory well, located 4,000' to the northeast of the base of open annulus in CD5-03,the shallowest oil show was encountered at 3,990' MD(-3,930' TVDSS),with a second show encountered at 4,115' MD(-4,055' TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These characteristics suggest the presence of only trace to minor quantities of oil in the geologic strata that will be affected by annular disposal in CD5- 03. At present,these shows are not believed to represent the presence of commercial quantities of oil. • • CD5-03 Annular Disposal September 27, 2016 Note to File Page 4 of 7 2150840 2150720 2150730 2151460 501032071400 181 ft 501032071100 21 ft 501032071200 40 ft 501032071800 s ► 4 ► 4 ► N CONOCOPHILLIPS CONOCOPHILLIPSCONOCOPHILLIPS CONOCOPHILUPS CRU CD5-313 360' CRU CD5-04 697' CRU CDS-05 503' CRU CD5-03 362 FNL 2870 FEL 310 FNL 2497 FEL 318 FNL 2517 FEL 305 FNL 2451 FWL TWP:11 N-Range:4 E-See.18 TWP:11 N-Range:4 E-See.18 TWP:11 N-Range:4 E-Set.18 TWP:11 N-Range:4 E-Sec 18 :____-7 : 17: _HI::: . . , -... .... 1 .( IL , = , 71— ' r.„._,L....,_ 17-- ___. ... , 4. ,,.. ___ . } - U t__ A.w - • S +; Surface .. ry ase of • 1 Casing rE ' Permafrost Shoes Upper ' ', i Confining . Interval I - f 1.. Most _ LikelyI 1 _- Disposal H. Interval xv r Lower _ __ Confining j L Beds 1 t. , Open I 1 ti t r f Annulus i - , • _ . r 7 r -TD=15946 113=18878 TD=17900 T0=20899 Figure 2. CD5-03 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; separation distance between wells is measured between the surface casing shoes) Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order No. 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. i • CD5-03 Annular Disposal September 27, 2016 Note to File Page 5 of 7 Injected Fluid vs Affected Area Surrounding CD5-03 Wellbore (Assumptions:30%porosity,50%native fluid displacement,aggregate cylinder 34'high) 180 -- ii- rti 160 — C 0 a 140 — m I 120 — • c 100 — G 80 10 O � O a' 60 C 40 . Q 4 20 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 40,000 45,000 50,000 55,000 60,000 65,000 70,000 Amount of Injected Fluid(barrels) Figure 3. CD5-03 Area Likely Affected by Annular Injection (Assuming piston-like,radial displacement of 50%of native formation fluids) The gamma ray curve recorded in CD5-03 indicates that about 34' of aggregate net siltstone and sandy siltstone are present within the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average porosity of about 30%at this depth. Based on these values,the volume of rock that will receive 70,000 barrels of injected waste material lies within a radius of about 157' from the wellbore, assuming uniform, radial, piston-like displacement of the native formation fluid occurs(Figure 3). • • CD5-03 Annular Disposal September 27, 2016 Note to File Page 6 of 7 Injected Fluid vs Affected Area Surrounding CD5-03 Wellbore (Assumptions:30%porosity,50%native fluid displacement,elliptical aggregate cylinder 34'high) 800 — — d 750 — — --- ---- ------ ---- • 700 — ------ ----- — — • . 650 lbs • • • 600 - — ------- -- --- --- • • 0 550 — ------------------ •— --------- • 500 — ---- -- ----- -- ♦ --- -------- L •450 • - ----------- ♦ ----- ------- • J• 400 — --- •- — --- — N 350 — • •X -,..,� — ---- ♦ — ---- ---- ¢ • 300 — • — ------ -- ------ o • 250 — -------------- • ----- --------- — --- s • d200 -------------- ♦ ---- --------------- --- h • v150 — — ---- ♦ --- — -------- • O 100 — • —- — ----- — --- U • to 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 40.000 45,000 50,000 55,000 60,000 65.000 70,000 Amount of Injected Fluid(barrels) Figure 4. Length of Semi-Major Axis(b) of Elliptical Cylinder Affected by CD5-03 Injection (Assuming piston-like,displacement of 50%of native formation fluids within in an elliptical cylinder having semi-minor axis length(a)of 35') The chart presented in Figure 5 provides an alternative estimate of the volume around CD5-03 that may be affected by the proposed annular disposal operations if horizontal permeability within the injection interval varies strongly in one direction.Again,the injection interval is assumed to be 34' thick,has 30%porosity, 50% of the native formation fluids are displaced by injected waste fluids, and horizontal permeability is assumed to be 10-fold smaller in a direction normal to that of the direction of primary permeability. If the injected waste fluids ultimately occupy an elliptical cylinder that has a semi-minor axis measuring 35' on either side of the CD5-03 wellbore,the semi-major axis of the affected elliptical cylinder may reach up to about 700' in length. The nearest surface casing shoe occurs in well CD5-08, which is located about 204' south of the surface casing shoe in CD5-03. If there exists a strong northwest-rending directional influence on horizontal permeability,injected fluids may reach the open annuli in CD5-02(223' east),CD5-06(280' south), CD5-09(268' west),CD5-12(487' south), CD5-05 (500' south)and they may even reach as far as CD5-01,which lies 615' southeast of CD5-03. However,the operator's surface casing cementing records from these wells suggest successful surface casing cementing operations,so the open annuli in these nearby wells should not provide pathways for migration out of zone or to the ground surface. Summary The limited volume of rock that will be affected by this proposed annular disposal program contains methane gas, is situated beneath more than 1,200' of permafrost, and is bounded above and below by continuous layers of claystone and mudstone. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no • • • CD5-03 Annular Disposal September 27, 2016 Note to File Page 7 of 7 freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. I recommend approving the request for annular disposal operations with CD5-03 up to 70,000 barrels. Patricia Bettis Senior Petroleum Geologist ��,,�� 4(1/74 • Bettis, Patricia K (DOA) From: Allen,Troyce B (Orbis Engineering, Inc.) <TroY ce.B.Allen@contractor.conocop p hilli s.com> Sent: Monday, September 26, 2016 3:16 PM To: Bettis, Patricia K (DOA) Cc: Anderson, Nina M; Njoku, Johnson;Alvord, Chip Subject: FW: CRU CD5-03 (PTD 215-146): Sundry Application for Annular Disposal-Additional Volume of Waste Patricia— In regards to your question below the packet is for the extension of the CD5-03 annual disposal permit. The AOGCC should already have on file the wells information that for all the wells with in the1/4 mile plot with the exception of CD5-06. This was a new well at the time we submitted the CD5-03 extension. Does this help? Thanks, TroyceCost Specialist ConocoPhillips 1700 G Street Anchorage,AK 99510 I Ph:907-263-4680 Email:Troyce.B.Allen@contractor.conocophillips.com From: Njoku,Johnson Sent: Monday, September 26, 2016 2:58 PM To:Anderson, Nina M <Nina.Anderson@conocophillips.com> Cc:Allen,Troyce B (Orbis Engineering, Inc.) <Troyce.B.Allen@contractor.conocophillips.com> Subject: FW: CRU CD5-03 (PTD 215-146): Sundry Application for Annular Disposal-Additional Volume of Waste Nina, Could you help me take care of this? Let me know if you have any questions or concerns. Best regards, Johnson Njoku Engineering Supervisor-Drilling +907 317 1529 "The Success of Every MIT Opportunity is Important,but what is most Important is the boldness to pursue the Opportunity and the Honest Optimism for Success"-JCN From: Alvord, Chip Sent: Monday, September 26, 2016 2:48 PM To: Njoku,Johnson <Johnson.Njoku@conocophillips.com> Subject: FW: CRU CD5-03 (PTD 215-146): Sundry Application for Annular Disposal-Additional Volume of Waste Johnson—could you check with whomever and get this sorted out? Thanks, 1 e • Chip From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, September 26, 2016 2:28 PM To:Alvord, Chip <Chip.Alvord@conocophillips.com> Subject: [EXTERNAL]CRU CD5-03 (PTD 215-146): Sundry Application for Annular Disposal-Additional Volume of Waste Good afternoon Chip, The AOGCC received the application for CD5-03 well. As part of the application,the cement detail report, daily drilling report and Well Equipment Description for CD5-06 was enclosed. I want to verify that the application is for CD5-03 and not CD5-06. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, September 26, 2016 2:28 PM To: Alvord, Chip Subject: CRU CD5-03 (PTD 215-146): Sundry Application for Annular Disposal-Additional Volume of Waste Good afternoon Chip, The AOGCC received the application for CD5-03 well. As part of the application, the cement detail report, daily drilling report and Well Equipment Description for CD5-06 was enclosed. I want to verify that the application is for CD5-03 and not CD5-06. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 11 L...- (1)O W '.mia CS o - o a iii 't o o ( o C a) O N N N O O w � p LL ‘-',4CO N U ° N,Q) No c N 03 7 OC) N co � N y L....- Z d1 a z N o o z z - O a) to ID al Fij _ a >Z Zco ET 75 N'� N a 4-5 cr 0 d > Q LLL. c • .z-:. O t 03 fQ .3 c m N: w ai m O Q0 ,O N O a o CO CO a_i V Z q ❑ N O Q o- � � o� oQ cn- OZ Q 1.L a) o Q ❑ O N .. ILI CO > a m J O_ Oo -E---r) 00 00 ai CL Q r2 o a m ,- 9 - o CO a) > J o s d > > O L Z cf) co c0 LLI CC LL Z ❑ N o r N 0 0 Z 0 0 > F o in C.) 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U T m p a3 O N o C E in @ d C a) W CD N C O Q U C d N co CO M CO Q U O CL O p O O W L [n d N M 22 N N N N Q — • G.L.Alvord Alaska Drilling Manager Drilling&Wells .0.Box Anchorage, AK AK 99510-0360 ConocoPhilhps Phone: 907-265-6120 July 6, 2016 Liz Link RECEIVED Alaska Oil and Gas Conservation Commission JUL 0 7 2016 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Annular Disposal Report, Second Quarter, 2016 Liz Link: Please find attached the second quarter 2016 annular disposal for the Kuparuk and Alpine wells. This report shows the volumes disposed into surface casing by production casing annuli during the second quarter of 2016, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2016. Please call Chip Alvord at 265-6120 or Troyce Allen at 263-4680 should you have any questions. Sincerely, e. o,t G. L. Alvord Alaska Drilling Manager • PTD z 5—/gam Loepp, Victoria T (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Monday, November 02, 2015 12:44 PM To: Loepp, Victoria T(DOA) Subject: Producer CD5-03 Operation Update(PTD 215-146) Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I want to give you a quick update on ConocoPhillips Alpine producer CD5-03 (PTD#215-146,API #:50-103-20718-00-00) operation over the weekend. We were running 9-7/8" intermediate casing in hole during weekend and after run to 12,460' MD, it appears that the formation was broken down and we were not able to build up circulation, all the other parameters still looks good. Due to the concern of shale below,we decided to continue run casing and successfully land casing on bottom at 14,340' MD on Sunday afternoon.After that,we proceeded to cement casing with 2 stages jobs as planned,there were no return for both stage cement jobs even though we did see some lift pressure for both cement jobs. Just want to keep you informed of what we saw during the weekend and please feel free to contact me if you have any questions. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 SCANNED SEP 2 0 2016 1 i 0 p , • O N G Nco N 0 Clco 4 GO \ Q UD O uD co M 6 6 O V7 . • O. N Z 77 -I 0 O O W 0 W O N O O N O m N Q I M 0121 on' U@ U 5 U URS 1T3 c U y O N IM a I Im (Ni a) a ca >_ 1 ai QUI •Q o Q o Q o Q Q Q 0 0 0 on 2 b 6 0 �0 U 10 W U0 U0 U0 112 U. 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GC ❑ ( Q L m l9 ~ L N N 3 = d > I w ai ++ c mv` rn O N J p 1 c 3 OO = / v O p f0 a O U N O N a U < a ❑ .L...G= c (7 N O N N O) c N 0) N v ❑ a) 3 0 •c o O C 7 ON U C N I Q a m oco as ❑ c v o N t U O O E O 0 3 co `8 N N @ MO m a) @ V O N a) 'O 112 I N Q o o c cv€ v, M Op c > .- > Q = N U E w U r H a O. a) L m co c O• 00 O ❑ ,_ c O c c N N W Q « N UO O .D h - O U 'O = fca as ❑ t as .. ,Z` E O O N a0 (:). O Y c U co E O U fn ❑ y in c 'O L L f0 p .,(Li Z p N N N a z N M rn d .. E O. O a) a) U a) w O N C N _ a) a) c C O < V •E d N co Co Co O '0 O a Z Zi Q N a) (n a d O p O O LLJ > �'' O L L- I- N M • .5 N N N N• r 0 - 27 1 57 STATE OF ALASKA ALOIA OIL AND GAS CONSERVATION COMMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations I Fracture Stimulate Y. Pull Tubing (- Operations Shutdown Performed: - Suspend Perforate ;rOther Stimulate i Alter Casing r Change Approved Program Plug for Redrill r. Perforate New Pool i Repair Well £...... Re-enter Susp Well i.... 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I Exploratory i 215-146 3.Address: 6.API Number: Stratigraphic P Service i P. O. Box 100360,Anchorage,Alaska 99510 50-103-20718-00 7.Property Designation(Lease Number): 8.Well Name and Number: ASRC NPR4,ASRC NPR2 CRU CD5-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Colville River Field/Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 20999 feet Plugs(measured) None true vertical 7332 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 13723, 14153 true vertical 0 feet (true vertical) 7254, 7380 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 115 115 SURFACE 2358 10 3/4 2393 2157 INTERMEDIATE 14306 7 5/8 14341 7399 LINER 6837 41/2 20990 7332 RECEIVED Perforation depth: Measured depth: 18,513-20,984 True Vertical Depth: 7,385-7,332 MAR 14 2016 AOGCC Tubing(size,grade, MD,and TVD) 3.5, L-80, 14167 MD, 7382 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 13723 MD and 7274 TVD PACKER- BAKER HRD-ZXP Liner Top Packer @ 14,153 MD and 7380 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 14871-18451 Treatment descriptions including volumes used and final pressure: Total Well -6 stages 490k placed ...See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1147 - 3 832 188 Subsequent to operation 4229 - 129 1630 236 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory 1— Development �- Service P Stratigraphic -- Copies of Logs and Surveys Run € 16.Well Status after work: Oil 1v.. Gas WDSPL Printed and Electronic Fracture Stimulation Data R- GSTOR i WINJ i WAG I— GINJ 1..... SUSP r- SPLUG I" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-014 Contact Robert Blaknev(a 265-6417 Email Robert.G.Blakney@conocophillips.com Printed Name Robert Blakney Title Completions Engineer Signature Phone:265-6417 Date //C �/� VTL 5//I/14CD Re ce i✓eA Form 10-404 Revised 5/2015 41A4 bRSDMS I.�- MAR 1 4 2016 Submit Original Only • • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 2/18/2016 Job End Date: 2/18/2016 State: Alaska , County: Harrison Bay Frac API Number: 50-103-20718-00-00 RKUS Operator Name: ConocoPhillips Company/Burlington Chemical Disclosure Registry Resources Well Name and Number: CD5-03 Longitude: -151.22291000 Latitude: 70.31362300 i, _Y . `___ szonsmanaism Datum: NAD83 "�"" "` C3il&CaaS Federal/Tribal Well: NO True Vertical Depth: 7,332 Total Base Water Volume(gal): 238,058 Total Base Non Water Volume: 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number ..oncentration in concentration in Comments Additive HF Fluid (CAS#) (% by mass)** (0/0 by mass)** Sea Water Operator Base Fluid NA NA 100.00000 79.66982Density=8.580 CarboLite 16/20 CarboCeramics Proppant NA NA LVT-200 Penreco Additive NA NA BE-6 MICROBIOCIDE,Halliburton Additive,Biocide, CL-22 UC,CL-31 Breaker,Crosslinker, CROSSLINKER, Gelling Agent, _OSURF-300D,MO- Microbiocide,Non- 67,OPTIFLO-III ionic Surfactant,pH DELAYED RELEASE Control Additive BREAKER,SP BREAKER,WG-36 GELLING AGENT NA NA Ingredients shown above are subject'6.'29 CFR 1910.1200(i)and appear on Material Safety Data Sheets(MSDS).Ingredients shown below are Non MSDS. Hazardous and Non- Hazardous Ingredients Ceramic materials and wares, 66402-68-4 100.00000 19.09706 chemicals Guar gum 9000-30-0 100.00000 0.26017 • • ater 7732-18-5 100.0000C 0.1584r 'otassium formate 590-29-4 60.00000 0.06187 :orate salts Confidential 60.00000 0.06187 thanol 64-17-5 60.00000 0.04752 •xyalkylated phenolic resin Confidential 30.00000 0.03168 odium hydroxide 1310-73-2 30.0000C 0.03045 'otassium metaborate 13709-94-9 60.00000 0.02604 eavy aromatic petroleum 34742-94-5 30.0000C 0.02376 aphtha •mmonium persulfate 7727-54-0 100.0000C 0.01864 :entonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01301 allow alkyl)dimethylammonium -tearate complex rystalline silica,quartz 14808-60-7 30.0000C 0.00570 ured acrylic resin Confidential 30.00000 0.00559 wrfactant mixture Confidential 1.00000 0.00520 •-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00410 'oly(oxy-1,2-ethanediyl),alpha- 127087-87-0 5.00000 0.00396 4-nonylphenyl)-omega- ydroxy-,branched aphthalene 91-20-3 5.00000 0.00396 .ilica gel 112926-00-8 1.00000 0.00260 'otassium hydroxide 1310-58-3 5.00000 0.00217 .odium chloride 7647-14-5 1.00000 0.00205 •crylate polymer Confidential 1.00000 0.001036enise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 671-6226 -odium glycollate 2836-32-0 1.00000 0.00103 -odium carboxymethyl cellulose 9004-32-4 1.00000 0.00103 ,2,4 Trimethylbenzene 95-63-6 1.00000 0.00079 -odium persulfate 7775-27-1 100.00000 0.00039 rystalline Silica,Quartz 14808-60-7 0.10000 0.00026 -odium sulfate 7757-82-6 0.10000 0.00000 ydrotreated Distillate,Light.. 64742-47-8 9-16 Total Water Volume sources may include fresh water,produced water,and/or recycled water "Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) • CD5-03 • DTTMS.JOBTYP SUMMARYOPS 2/18 FRACTURING pumped 6 stage frac on CD5-03. 490k lbs of 16/20 carbolite placed 2/22 DRILLING MADE MULTIPLE FB-BRUSH RUNS &2.5" DD BAILER FROM 4856' -7305' SLM. SUPPORT- **RECOVERED 11" X 1/4" PIECE OF TREE SAVER ELEMENT & FIBERS FROM CAPITAL SAND BAG/ NO FRAC SAND IN BAILER**. IN PROGRESS. 2/23 DRILLING MADE MULTIPLE BRUSH RUNS WITH 2 & 3 PRONG WIRE GRABS. RAN 2.5" SUPPORT- PUMP BAILER TO 9498' SLM. **RECOVERED SAMPLE OF X-LINKED GEL AT CAPITAL 9500' SLM**. PUMP 40 BBLS HOT DIESEL DWN TBG TO FLUSH GEL BELOW DS NIPPLE AT 13756' RKB. RAN BRUSH & GAUGE TO 13756' RKB. SET 2.81" CAT STANDING VLV @ 13756' RKB. IN PROGRESS. 2/24 DRILLING PULLED DV's @ 13603' & 10045' RKB's. SET 1/4" OV @ 13603' RKB. RAN SUPPORT - POCKET BRUSH TO 10045' RKB TO CLEAN POCKET.ATTEMPT TO SET GLV @ CAPITAL 10045' RKB. NOT ABLE TO GET ALL THE WAY IN POCKET (MULTIPLE SCRAPE MARKS UP SIDE OF GLV). IN PROGRESS. 2/26 DRILLING BRUSH & FLUSH GLM @ 10045' RKB TAKING RETURNS TO FLOW LINE ON CD5- SUPPORT- 05. SET GLV(TRO = 1913) @ 10045' RKB (CAME BACK w/ FN,RN &WOBBLE CAPITAL RING/ NO-GO &VLV IN POCKET). PULL DV @ 6667' RKB. REPLACE WITH 3/16" GLV (TRO = 2023). PRESSURED TBG TO 1200 psi. HOLDING. NO INCREASE ON IA. IN PROGRESS. 2/28 DRILLING ATTEMPT TO PULL GLV @ 10045' RKB. MITT TO 2500 psi. **PASS**. PULL 2.81" SUPPORT- CAT STANDING VLV @ 13756' RKB. **READY FOR FLOW BACK**. CAPITAL 2/28 PUMPING PUMP 10BBLS METH DOWN IA (JOB COMPLETE) WNS OD CD5-03 onocoPhillips &N.. Well Attribu Max Angle D TD Alaska Inc •°3 i' Wellbore APVUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Darrocom,,,,i s 501032071800 ALPINE PROD 94.22 19,183.81 20,999.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CDS-03,319/20161:40:47.PM SSSV: NIPPLE Last WO: 36.83 11/20/2015 Verdes'schemaLp4aohreD Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: GLV C/O pproven 3/3/2016 HANGER;31.5 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WELen(I...Grade Top Thread Conductor 20 19.000 35.9 115.0 115.0 78.60 L-80 Welded f • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Surface 10 3/4 9.950 35.9 2,393.4 2,156.9 45.50 L-80 Hyd 563 IIIntermediate I�',,,�Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 11 Intermediate 75/8 6.875 34.5 14,340.7 7,399.0 29.70 L80 BTCM Conductor;35.0-175.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 00 Reducing;121.6 T 1 Production Liner 4 1/2 3.958 14,152.6 20,990.0 7,332.1 12.60 L-80 IBT-M Liner Details Nominal ID I Top(ftKB) Top(TVD)(1KB) Top Inoi(') Item Des Com (in) 14,152.6 7,379.7 81.16 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.250 14,174.0 7,382.8 81.85 NIPPLE BAKER RS PACKOFF NIPPLE 4.000 14,176.3 7,383.2 81.93 HANGER BAKER FLEX-LOCK LINER HANGER 4.170 • • • • 14,191.1 7,385.2 82.41 XO Reducing Cross over,5"BTC-M x 4-1/2"Hyd 563 3.920 • • 14,801.1 7,395.0 91.64 SLEEVE CAMCO SLIDING SLEEVE'D'PROFILE,OPEN 2.750 DOWN 14,871.0 7,393.1 91.59 FRAC PORT FRAC SLEEVE#9,4 1/2",Ball Act,2.063"(2.05"ID) 2.050 Solace;ass-z,353.4 15,617.8 7,390.1 89.55 FRAC PORT FRAC SLEEVE#8,4 1/2",Ball Act,2.000"(1.954"ID) 1.954 I GAS LIFT;6,666.7 f, 16,487.4 7,394.5 91.11 FRAC PORT FRAC SLEEVE#7,4 1/2",Ball Act,1.938"(1.890"ID) 1.890 I { 17,099.7 7,385.4 89.93 FRAC PORT FRAC SLEEVE#6,4 1/2",Ball Act,1.875"(1.83"ID) 1.830 17,711.1 7,380.4 90.39 FRAC PORT FRAC SLEEVE#5,4 1/2",Ball Act,1.813"(1.77"ID) 1.770 GAS LIFT;10,045.0 11 18,451.5 7,383.3 88.23 FRAC PORT FRAC SLEEVE#4,4 1/2",Ball Act,1.75"(1.71"ID) 1.710 Tubing Strings Tubing Description TUBING 1String 3Ma.112.. I'D (in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 2.992 31.5 14,)67.0 7,381.8 9.30 L-80 EUE GAS LIFT;13,802.9 . Completion Details I Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top not I) Item Des Com (in) • 31.5 31.5 0.12 HANGER FMC HANGER 3.958 GAUGE;13.662.1 '• 121.6 121.6 0.42 XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 0 2.91" ® 553.5 553.4 3.74 NIPPLE CAMCO LANDING DS NIPPLE 2.875 XO Threads;13,719.0 1 13,662.1 7,254.2 70.00 GAUGE 3-1/2",SLB Solid Gauge Mandrel with I-wire 2.913 PACKER 13'723.4 13,723.4 7,274.4 71.56 PACKER BAKER PREMIER PACKER 2.880 XO Threads;13,731.4 III 13,756.0 7,284.5 72.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 3.000 14,149.7 7,379.2 81.07 LOCATOR LOCATING SUB liI 14,150.4 7,379.3 81.09 SHOE BAKER WLEG 2.970 LOCATOR;14,149.7 Perforations&Slots Shot SHOE;14,150.4 I:,75 Dens `I +] Top(ND) Btm(ND) (shots/ f' '.1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com r { 18,513.1 20,933.5 7,385.4 7,332.8 11/16/2015 SLOTS 2 X 1/4"X 16 SLOTS/FT 20,975.0 20,984.7 7,332.3 7,332.2 11/16/2015 PERFP PERF PUP 36 -.5"HOLES Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ft813) (ftKB) (ftKB) (ftKB) Type Date Com Intermediate;34.5-14.340.7 14,871.0 18,451.0 7,393.1 7,383.3 Sand Frac 2/18/2016 Pumped stages 1-6,490,000 lbs of 16/20 Carbolite placed.ISIP-4,296 psi-BHG Mandrel Inserts I St ati N Top(TVD) Valve Latch Port Size TRO Run (I fi Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com II Il 1 6,666.7 4,113.0 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 2,023.0 2/26/2016 2 10,045.0 5,641.4 Camco KBMG 1 GAS UFT GLV BK-5 0.188 1,913.0 2/26/2016 3 13,602.9 7,233.3 Camco KBMG 1 GAS UFT OV BEK 0.250 0.0 2/24/2016 Notes:General&Safety End Date 1 Annotation NOTE' [t Sand Sand Frac;14,871.0 Q II i I 4I [ II SLOTS;18,513.1-20,933.5 a PERFP;20,975.0-20,984.7 -.1 Produ0Eon Liner;14,152.6- 20,980.0' 1.,OF 7,4 • ,„$, 177,',s, THE STAT• Alaska Oil and Gas ��\\ rte O f T Conservation Commission dAsKA_ _ _ 333 West Seventh Avenue 11010X.71 '/ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Robert Blakney Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-03 Permit to Drill Number: 215-146 Sundry Number: 316-014 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster ,} Chair DATED this �`tb day of January, 2016. RBDMe JAN 151016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 7 z 1 APPLICATION FOR SUNDRY APPROVALS 14 ,� 20 AAC 25.280 A() C 1.Type of Request: 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: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory ❑ Development Q . 215-146 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20718-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD5-03 • Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): ASRC NPR4, ASRC NPR2 ' Colville River Unit!Alpine Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 20,999' • 7,332' • 7,000 Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 2,358' 10-3/4" 2,393' 2,156' Intermediate 14,305' 7-5/8" 14,340' 7,399' Production Liner 6,690' 4-1/2" 20,990' 7,332' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" L-80 14,167' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM INSTALLATION no SSSV ' 13,723'MD/7,247'TVD no SSSV 12.Attachments: Proposal Summary E Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 1st,2016 OIL 2 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Robert Blakney @ 907-265-6417 Email Robert.G.Blakney@conocophillips.com Printed Name Robert Blakney Title Completions Engineer I /7 / 1 Signature Phone 907-265-6417 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No F Spacing Exception Required? Yes ❑ Noe Subsequent Form Required: /0— 4 0 If-- APPROVED BY Approved by: r7"'� COMMISSIONER THE COMMISSION Date: /�/¢^/� 4 (714/go p� ii il1'1� Submit Form and Form 10-403 evised 11/2015 n f a frojIasi'ANe IIien'�proval. Attachmentslicate ORte1NAt GDh/l/ll�l6 b•rt-;'/4: WNS PROD ! CD5-03 ConocoPhillips 11135 Well Attributes Max Angle&MD TD Al i ,t: Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) , e1,,,c 501032071800 ALPINE PROD 94.22 19,183.81 20,999.0 --- Comment 6125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 055-03.12/18/20158:26:43 AM SSSV: NIPPLE Last WO: 36.83 11/20/2015 Vertical schemallc!actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL.GLV C/O lehallf 12/17/2015 HANGER',31.5 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Conductor 20 19.000 35.9 115.0 115.0 78.60 L-80 Welded _... ... .... .. ... j .. ....Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 1 Surface 10 3/4 9.950 35.9 2,393.4 2,156.9 45.50 L-80 Hyd 563 7`aE"` ""'a" `1iuci,ii oc nr�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SMrs Intermediate 7 5)8 6.875 34.5 14.340.7 7,399.0 29.70 L80 BTCM Conductor 359 1150j t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wtl .Len(I.. Grade Top Thread j XO Redudng:1215 ilk Production Liner 41/2 3.958 14,152.6 20.990.0 7.332.1 12.60 L-80 IBT-M i Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 14,152.6 7,379.7 81.16 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.250 14 174.0 7,382.8 81.85 NIPPLE BAKER RS PACKOFF NIPPLE 4.000 14,176.3 7,383.2. 81.93 HANGER 'BAKER FLEX-LOCK LINER HANGER 4.170 F.. 14,191.1 7,385.2 82.41 XO Reducing 'Cross over,5"BTC-M x 4-1/2"Hyd 563 3.920 14,801.1 7,395.0 91.64 SLEEVE CAMCO SLIDING SLEEVE'D'PROFILE,OPEN 2.750 DOWN 14,871.0 7,393.1 91.59 FRAC PORT FRAC SLEEVE#9,4 1/2",Ball Act,2.063"(2.05"ID) 2.050 Surface:359-23933 ( 15.617.8 7,390.1 89.55 FRAC PORT FRAC SLEEVE#8,4 1/2",Ball Act,2.000"(1.9541D) 1.954 GAS LIFT.66667 16,487.4 7,394.5 l. 91.11 FRAC PORT FRAC SLEEVE#7,4 1/2",Ball Act,1.938"(1 890"ID) I 1.890 17,099.7 7,385.4 89.93 FRAC PORT FRAC SLEEVE#6,4 1/2",Ball Act,1.875"(1.83"ID) 1.830 I' I/ 17,711.1 7.380.4 90.39 FRAC PORT FRAC SLEEVE#5,4 1/2",Ball Act,1.813"(1.77"ID) 1.770 , GAS LIFT,10.045 0 t 18,451.5 7,383.3 88.23 FRAC PORT FRAC SLEEVE#4,41/2".Ball Act,1.75"(1.71"ID) 1.710 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..°Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 31.5 14,167.0 7381.8 9.30 L-80 EUE Completion Details GAS LIFT',13"0029 E 1 Nominal ID Top(ftKB) Top(ND)(111(13) Top Incl(°) Item Des Com (in) 31.5 31.5 0.12 HANGER FMC HANGER I 3.958 GAUGE.13 662.1 121.6 121.6 0.42 XO Reducing XO.4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 2.91" 553.5 553.4 3.74 NIPPLE CAMCO LANDING DS NIPPLE 2.875 xo Threads 13.71s 0 13,662.1 7,254.2 70.00 GAUGE 3-1/2",SLB Solid Gauge Mandrel with I-wire 2.913 PACKER'.13.723 4 13,723.4 7,274.4 71.56 PACKER BAKER PREMIER PACKER 2.880 X0 Threads:13.731.4 13,756.0 7,284.5 72.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 14,149.7 7,379.2 81.07 LOCATOR LOCATING SUB 3.000 14.150.4 7.379.3 81.09 SHOE BAKER WLEG 2.970 Perforations&Slots LOCATOR:14.149.7 Shot If'..l Dens SHOE:14.150 150.4 Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (kKB) (ftKB) Zone Date t) Type Com 18.513.1 20,933.5 7,385.4 7,332.8 11/16/2015 SLOTS 2 X 1/4"X 16 SLOTS/FT 20,975.0 20,984.7 7.332.3 7,332.2 11/16)2015 PERFP PERF PUP 36 I -.5"HOLES Mandrel Inserts � St ah on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OO(in) Sery Type Type (in) (psi) Run Date Corn mtermemate:Sas-143407 �) 1 6,666.7 4,113.0 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 2.023.0 11/23/2015 I 3 2 10,045.0 5,641.4 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 1,913.0 11/22/2015 3 13,602.9 7,233.3 Camco KBMG 1 GAS LIFT OV BEK 0.250 0.0 11/22/2015 Notes:General&Safety End Date Annotation NOTE: II II SLOTS',18,513.1-20.933.5 -[1- PERFP.20.975 0-20 984 Production Liner',14.152.6- 20 9909 • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO TH•ASKA OIL AND GAS CONSERVATION COFSSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Garrett B. Haag Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-03 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) Garrett B. Haag, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Garrett B. Haag. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On December 15, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 15th day of December, 2015. 14 arre'tt B. Haag STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 15th day of December, 2015, by Garrett B. Haag. Notary Public, State of Alaska My Commission Expires: 4 STATE OF ALASKA ��. 4 NOTARY PUBLIC REBECCA SWENSEN , `My Commission Expires Aug.27,2016 • • P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhi I I i ps Alaska, Inc. Garrett B.Haag,Staff Landman Land Department,ATO 1480 Phone (907)265-6297 Fax (907)263-4966 Garrett.B.Haag@cop.com December 15, 2015 VIA CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1)for CD5-03 Well AA-092347,ASRC NPRA-01,ASRC NPRA-02,ASRC NPRA-03,ASRC NPRA-04,and ADL 388466 Colville River Unit,Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAP") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-03 Well(the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 6, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases, ASRC NPRA-04 and ASRC NPRA- 02 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 305 2,451 11N 4E 18 Umiat Heel 4,729 637 12N 4E 31 Umiat Bottomhole 4,296 3,679 12N 4E 30 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information,please contact the undersigned. Sincerely, 4..11B14 Garrett B. Haag -7 Staff Landman Attachments: Exhibits 1 &2 • 0 Exhibit 1 i t.... - -' ConocoPhillips ADL38842A° I CD5-03 WellAlas-ca+ 09Dec15 T12NR3E ASRC-NPR1 i t p4s i i i ASRC-NP R2 I I 41/410I LI- f'7 1F' Alpine PA ASRC-hEPR4 • , i ASRC•NF !1, i 3 i !t I T11NR3E / / r1tN R4E i ids, i AAO 87888 ------- I AAO 9234' ASRC-NPR4 I A,DL38723£ II • Frac Point ' Open Section References: Odell Data:ConocoPhillips.Alaska Technical Database(ATDB) N Well Trajectory Surface Facilities:Nuiqsut Pad Published 06/09/15 1/2 h9i.Radius E Alpine PA 0 0.25 0.5 0.75 1 0 CPAI Lease Miles • • Exhibit 2 Operator& Owner: ConocoPhillips Alaska,Inc. 700 G Street, Suite ATO 1220(Zip 99501) P.O. Box 100360 Anchorage,AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver,CO 80202 Attention: Mike Nixson,Director Land-Alaska Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa Imm,Resource Development Manager United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue, #13 Anchorage,Alaska 99513 Attn: Branch Chief,Energy and Minerals CC: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501-3560 Attention: Director Surface Owners: Kuukpik Corporation P.O.Box 89187 Nuiqsut,AK 99789 Attention: Mr.Isaac Nukapigak,President United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue,#13 Anchorage,Alaska 99513 Attn: Branch Chief,Energy and Minerals 0 • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles E ConocoPhillips Actss eeAlaska I - CD5-03 Fault Analysis 10Dec15 i SqTI2NR3E _..3 4 R4 _ 1 ASRC-NPRf I ....._.... I . IlkI ASRC-NPR2 E 3 I I 1 I _ . AO,1 I 1 -----1 t7 1 a � Alpine PA ASRC-NPR4 i h ASRC-NPR3 A- 1 1 —_ I AO92347 �------ T11NR3E i 1 T11-NR4E i___ _ __ i ccs}° + i 21, i AAOE71MS u• \ —-----j „ \ i AA092347 ! t�R4 I 3 ADL3$7208 ff 1 1 —Well in 142 Mi Radius of Open Section —Well in 112 Mi Radius of Trajectory References: :`.ell Data:ConocoPhillipsA,laska Technical Datatase(.ATOP, = Open Section Surface Facilities:Nuiqsut Pad Putlished 06109115 --Well Trajectory N U 112 Mi.Open Section Radius 0142 Mi Trajectory Radius 0 0.25 0.5 0.75 1 E Wpine PA Miles • Table 1 : Wells within .5 miles Well Name API Drill Site Status Well Type CD5-314 ' 501032070700 CD5 SUSP N/A CD5-315 • 501032071600 CD5 ACTIVE INJ NUIQSUT 1 ' 501032025300 N/A PA N/A CD5-04 • 501032071100 CD5 ACTIVE PROD CD5-05 . 501032071200 CD5 ACTIVE PROD CD5-315PB1 • 501032071670 CD5 PA N/A CD5-313PB1 - 501032071470 CD5 PA N/A CD5-313 • 501032071400 CD5 ACTIVE PROD CD2-78 • 501032060100 CD2 ACTIVE INJ • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half . mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, • Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." • SECTION 4 - PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 10 & 3/4" casing cement pump report on 10/21/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement, displaced with 10ppg mud. Full returns were seen throughout the . job. The plug bumped at 1,000 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 11/1/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement, displaced with 11.1 ppg LSND. No returns were seen. The plug bumped at 320 psi, and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 10/23/2015 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 11/4/2015 the 7-5/8" casing was pressure tested to 3,500 psi for 30 mins. The 3.5" tubing will be pressure tested to 3,500 psi prior to frac'ing. The 7-5/8" casing will be pressure tested to 3,500 psi prior to frac'ing. • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Wellbore pressure ratings • • Stimulation Surface Rig-Up 2. 2 1 Tank, i I. L Tale Tank a f ti , ,...Ami „ /, 'R' 2 VI IS U • Minimum pressure rating on all surface F:+08( treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi m _ • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 ko v psi. t N r c PF MI cd u ar 4mil dulnd u Pu) 'Dff"Tana 13 E Di g w © -, Pump Truck Pop-af Tank J (f' C 4 iij F M II Fra;Pur-a p...Al . °ti l'!`,i Fra,Purr P Frar rump hail ♦'. N Z. ...] Fra-Ps-ur'p Fran Pump hall tir..; CO: I`,.1 Fran Purmp • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION ('-'i,v.;3-, L.) VA;,,q,,M.,:„,;1,6i,.;-'1i•u",q. i',,,,A",'",;:::,,,,, NAR'LL2,1 FRAC IRON ; I •-•/*CONNECTION , ...,- 5.. ,/-5-i-- <,-- ,,- ....v.- i „REMOTE OPERATED AroBLA ,4,,,, MASTER VALVE k-i,-,,,iy /,-mANtiAt,(we RATED .— , ,,-.. MASTER VALVE .44 .15,4 Stif_i_. i,„_ ; –.IN'1'' •Olfk,_„,inger \ , Stinger \r MANDREL LI . 1' , 1 , af\ / ..,''' 4 . ,...., ---\_ ,) • , . 'Mt, ----il — „ / , ..... ,-7 mi, „,,rLoW TEE AND /41 '11 9,...,,,,,,t VENT VALVE WELWEAD 'r11 VALVES- ''. / OPEN .....,... ,., .....„, 14 cum)PACKOFF ASSEMBLY IN L i - - ' f PLACE ILL TURBYG B L — TUBMG --..:,--, I ' 1 • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 Y2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75"mandrel 36 bpm • • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick at the heel of the • lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 14,262' MD/7,322 TVDSS. The estimated fracture gradient for the Alpine A sandtone is 12.5 ppg. The overlying confining zone consists of greater than 250' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the • Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 13,298' MD/7,040' TVDSS. The underlying confining zone consists of approximately 1800' of Kingak shales. The estimated fracture gradient for the Kingak shales is 15-18 ppg. Fracture gradient increases down section. The top of the Kingak interval ranges from 7470' TVDSS at the heel to 7525' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-03 wellbore). • • 0 a eA 0 S. a N am a0 v yrU O E al g ch 0 c o E N N^ V W 8 V R Y Y /lam` °6 IT O N M NH N Lri 0 ,aH vG p OWN N 0 3 3 2 cC O_ O_ Y, 'G C 0 O N O R O a C w b O U =C c O N L d d G L L W va O a •` 0 O QJ CC O O do -.§ C CO G _ JI-as N ^' a u W O Eu 8 Qco C 0 c▪o E • o o A b n r r Eo r .4•• •I N N C L E to to oam mo}+ o-- a. ti V o CO 3.- U- m R m ro a G 0 c-- c "iv _.I h e Nto o '" a 0 r U N .-&, co to C NN . Alln n n-, 1.VI I- Q 0 0 ? cc • a a a• m `4 n M f10 N 0 U In 0 0 V • • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: CD5-314: CD5-314 was plugged and abandoned per state regulations on 5/10/2015. CD5-315: The 7-5/8" casing cement pump report on 10/3/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug did not bump and the floats held, and pressure was held on the cement. NUIQSUT 1: The 9-5/8" casing cement pump report on 4/04/1998 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement. Full returns were seen throughout the job, and the plug bumped. The Nuiqsut 1 was then plugged and abandoned per state regulations on 4/13/1998. CD5-04: 7-5/8" casing cement pump report on 6/10/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 900 psi and the floats were checked and they held. CD5-05: The 7-5/8" casing cement pump report on 8/27/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Qannik Slurry cement, displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1700 psi and the floats did not hold. Pressure was held on the cement. CD5-315PB1: CD5-313PB1 was plugged and abandoned per state regulations on 9/24/2015. CD5-313PB1: CD5-313PB1 was plugged and abandoned per state regulations on 7/14/2015. CD5-313: The 7-5/8" casing cement pump report on 7/25/2015. Full returns were not seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 11.1 ppg LSND. The plug bumped at 1,140 psi and the floats held. • • CD2-78: The 7-5/8" casing cement pump report on 8/29/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.7 ppg mud. Full returns were seen throughout the job. Did not bump plug. 410 psi held on cement head. • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that two faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-03. These faults were interpreted from log data while drilling the lateral. They are not mapped (plat 2) with seismic and are interpreted to have throws less than 5 feet. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore:Because of this the fractures will only intersect faults that intersect the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. • If there are indications that a fracture has intersected a fault during fracturing operations, ' ConocoPhillips will go to flush and terminate the stage immediately. Well Depth Depth Vertical Loss Nearest Estimated Distance Displacement Frac Port Propped from Name MD (ft) TVDSS(ft) (ft) (bbls/hr) (ft MD) XF (ft) fault (ft) CD5-03 16,087 7,322 <5 120 16,487 140 ' 167 CD5-03 18,070 7308 <5 • none 17,711 140 219 CD2-78 21,192 7348 <5 80 N/A N/A N/A CD5-04 no faults intersected Table 3 —Drilled faults • • Plat 2: CD5-03 Fault Analysis 1 i L. - ' ConocoPhillips ADL388466 y flIaska I CD5-03 Fault Analysis ';t 10Dec15 i T2N R3E i ASRC-?NP R1 I I I i ASRC-PLP R2 7. i 1 e I 'a -----1 a 1 of 2 ,c,, Alpine PA P ASRC-PLP R4 I 7 2 ft x f 11�' ASRC-NPR3 P /JfP 11 is AA092347 T1INR3E i i 5 r11-r R4E Via— --------------t— - t AA087888 ,42? -- I i I I AA092347 AS -NPRa I ACL387208 1 —Well in 1/2 Mi Radius of Open Section —Well in 1/2 Mi. Radius of Trajectory References: Well Data:ConocoPhillips Alaska Technical Database(ATDB) Open Section Surface Facilities:Nuiasut Pad Published 06;09115 --Well Trajectory N 01/2 Mi.Open Section Radius 01,2 Mi Trajectory Radius 0 0.25 0.5 0.75 1 C^Alpine PA Miles • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-03 was completed in 2015 as a horizontal producer in the Alpine A formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 1,000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off syst tme o ensure lines are clear and all components are functioning properly. 8. Pump the 300 bbl breakdown stage (25# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3 500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7,000 psi. • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 1 • 300 bbls HYBOR G Pad • • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 2 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 3 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 4 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 5 • 340 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 110 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/6 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 7 ppa 16/20 Carbolite • Flush with 134 bbls of linear fluid • Freeze protect • Total Sand: Approx: 554,484 lbs 16/20 Carbolite Note due to time constraints the hydraulic fracturing treatment might get split into 2 days of pumping. 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 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O C 0 U Hydraulic Fracturing Fluid Product Comilt Information Disclosure • Fracture Date 2015-12-12 State: Alaska County: Harrison Bay API Number: 5010320718 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: CD5-03 Longitude: -151.22 Latitude: 70.31 LonglLat Projection: Production Type: True Vertical Depth(TVD): 7,332 Total Water Volume(gal)*: 236,700 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Abstract Concentration in Concentration in Ingredient Mass Comments Service Number Additive(%by HF Fluid(%by lbs (CAS#) mass)** mass)** Sea Water Operator Base Fluid NA NA 100.00. 78.06049% 2021412 Density=8.540 BA-20 BUFFERING AGENT,BE-6 MICROBIOCIDE, Additive,Biocide, CL-22 UC,CL-31 Breaker,Buffer, CROSSLINKER, Crosslinker,Gelling LOSURF-300D, Halliburton NA NA 0 NA Agent,Microbiocide, MO-67,OPTIFLO- Non-ionic Surfactant, III DELAYED pH Control Additive RELEASE BREAKER,SP BREAKER,WG-36 GELLING AGENT CarboLite 16/20 CarboCeramics Proppant NA NA 0 NA 1,2,4 Trimethylbenzene 95-63-6 1.00 0.00069% 18 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00139% 36 Acetic acid 64-19-7 30.00, 0.00510% 133 _ Denise Tuck, Halliburton,3000 N.Sam Houston Acrylate polymer Confidential 1.00% 0.00093% 25 Pkwy E., Houston, TX 77032,281- 871-6226 Ammonium acetate 631-61-8 100.00% 0.01702% 441 Ammonium persulfate 7727-54-0 100.00% 0.01830% 474 Bentonite,benzyl(hydrogenated tallow alkyl)dimethylammonium 121888-68-4 5.00% 0.01193% 296 stearate complex Borate salts Confidential 60.00% 0.05581% 1446 Ceramic materials and wares, 66402-68-4 100.00% 21.41241% 554484 chemicals Crystalline silica,quartz 14808-60-7 30.00% 0.00558% 146 Crystalline Silica,Quartz 14808-60-7 0.10% 0.00023% 6 Cured acrylic resin Confidential 30.00% 0.00599% 143 Ethanol 64-17-5 60.00% 0.04129% 1070 Guar gum 9000-30-0 100.00% 0.22853% 5918 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02065% 535 Naphthalene 91-20-3 5.00% 0.00399% 90 Oxyalkylated phenolic resin Confidential 30.00% 0.02753% 714 Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00399% 90 branched Potassium formate 590-29-4 60.00% 0.05581% 1446 Potassium hydroxide 1310-58-3 5.00% 0.00195% 38 Potassium metaborate 13709-94-9 60.00% 0.01799% 452 Silica gel 112926-00-8 1.00% 0.00229% 60 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00093% 25 Sodium chloride 7647-14-5 1.00% 0.00163% 44 Sodium glycollate 2836-32-0 1.00% 0.00093% 25 Sodium hydroxide 1310-73-2 30.00% 0.02104% 545 Sodium persulfate 7775-27-1 100.00% 0.00081% 21 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00957% 120 Water 7732-18-5 100.00% 0.12058% 3125 *Total Water Volume sources may include fresh water,produced water,and/or recycled water _ **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets(MSDS).As such,the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's(OSHA)regulations govern the criteria for the disclosure of this information.Please note that Federal Law protects"proprietary","trade secret",and"confidential business information"and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i)and Appendix D. • • a� -o Q o a) 2 c a < U- op co a) 4-• .A= • • .. - ' O O N O N CD O CO O O O .- O CO CD 0) N- t d- Cr) E O co O) co O 00 co in Cfl co C ..- N I-- N d COCOCrM N C: � a) O U' " c .0 En 4) a co 0 0 0 0 0 NNNNNN C — — — C O, CO CD CO CD CD CD CL.Q a) m m Cu Cu Cu J J J J J J O !r.; L- 'C/) 0 0 0 0 0 0 Q -2 -2 -2 -2 Q 0 0 0 0 0 0 CD 0 is — C 05) 0 0 0 0 0 0 0 CL 0 0 0 0 0 0 N Cr) 4 CD ai) T-- d. CAIP D _ O :O L.L. LL LL LL LL LL co = SIC` SIC` IC SIC' SIC' ^C O CO .L CU C c Cll N N N N N L- C) > I L — -0 -0 -0 -0 -0 -0 0 cf) C2 f/) CO CQ CB Ca CO CB (ll o f _C C J J J J J J D a 0O D LL ( d C C -1- -1-, .4--, -1- (6 1.I. 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N mi V ss •a 1 V 41.) o •a aCC o 0 a U V U N o •z s a I v dpU -az, d I j Z U vJ 0 �� OF Tits' • � \ I%% sA THE STATES Alaska Oil and Gas ) 7`A ofA Conservation Commission LASKA_ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4,ALAS'� Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, CRU CD5-03 Permit to Drill Number: 215-146 Sundry Number: 315-762 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Chair DATED this a y of January, 2016. RBDMS JAN 1 11 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION b 1 14 ANNULAR DISPOSAL APPLICATION AOGGC 20 AAC 25.080 1.Operator 3. Permit to Drill Name: _1 15-146 • ConocoPhillips Alaska 4.API Number: 50-103-20718-00-00 2.Address: 5.Well P.O. Box 100360,Anchorage,Alaska Ci-v CD5-03 6. Field: Colville River Unit- Alpine Pool • 7. Publicly recorded wells 8.Stratigraphic description: a)All wells within one-quarter mile: a)Interval exposed to open annulus: CD5-04, CD5-05 ,CD-313, CD5-09 Torok and Seabee formation,shale,siltstone and sandstone b)Waste receiving zone: b)water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,342' MD and 1,320'TVD None 11. Previous volume disposed in annulus and date: 12.Estimated slurry density: 13.Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal • 1929 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel,formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1-Jan-16 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17.Attachments: Well Schematic(Include MD and TVD) Cement Bond Log(if required) ❑ FIT Records w/LOT Graph Surf.Casing Cementing Data El Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. I, Signature: 4.(, (tet._ Title: Ne1(lu`S Printed Phone Name: Chip Alvord Number: 265-6120 Date: Rill hi is- Commission sCommission Use Only Conditions of approval: LOT review and approval: 1 Subsequent form required: ��`� Approval number: 3 tf- —f `C /--- RBDMS ' N 1 1A i 'LVED BY Approved by: ot ' P COMMISSIONER T-1 OMMISSION Date: Q / i� S. Form 10-403AD ev.6/2004 RIGINAtIONS ON REVERSE Submit in Dug'cate //8/K, Ohl JLI2o1� /'' t2 .3/,/C ConocoPhillips Alaska,Inc. • • Post Office Box 100360 • • Anchorage,Alaska 99510-0360 ConocoPh i i i i PS Telephone 907-276-1215 REG ED December 10, 2015 Alaska Oil and Gas Conservation Commission DECI " 2015 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 ' Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-03 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-03 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD5-03 approximately January 1st, 2016 or earlier depending on permit approval status. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Plan View of Adjacent Wells 4. Surface Casing Description 5. Surface Casing Cementing Report&Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report(LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report&Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. List of wells on CD)pad and the lateral distance from the surface casing shoe 11. Information regarding wells within 1/4 mile radius at AOGCC: CD5-04, CD5-05, CD5-313, CD5-09. 12. Information regarding remaining wells within t/4 mile radius included in sundry package: N/A 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT(14.8 ppg)occurred at a lower equivalent mud weight than the casing shoe FIT(17.2 ppg). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT. If you have any questions or require further information, please contact Nina Anderson at 265-6403 or Chip Alvord can also be reached by calling 265-6120. Sincerely, // J Niaf:' 1 Anderson Drilling Engineer cc: CD5-03 Well File Chip Alvord ATO-1570 Annulus Disposal Transmittal Form - e1 CD5-03 AOGCC Regulations,20 AAC 25.080(b) 1 Designation of the well or wells to receive drilling wastes: CD5-03 /y 2 The depth to the base of freshwater aquifers and permafrost,if There are no USDW aquifers in the Colville River Unit. • j, present. Estimated base of Permafrost= 1320' TVD(RKB) lv 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and lJ� annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the 4 11 not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 IV ° ti to 18000 mg/1. (Ref.AOGCC Conservation Order No.443, March 15. 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud,drilling cuttings,reserve disposed of and the estimated density of the waste slurry. pit fluids,cement-contaminated drilling mud,completion fluids,diesel,formation fluids associated with the act of drilling a well,drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings,and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be Humped is 35.000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate,mud plant rinse fluid generated by rinsing waste under(h)(3)of this section. tanks and equipement after producing drilling/completion fluid(see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1929 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports,LOT/FIT reports and base of any freshwater aquifer and permafrost,if present,and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the The top of cement is 6877'MD in the intermediate casing depth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this depth 12 The duration of the disposal operation,not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and,if so,a summary of the dates of the disposal operations,the volumes of waste disposed of,and the wells where the drilling waste was generated. 14 The well(s)where the drilling waste to be disposed of was or CD5-03,CD5-04, CD5-05 CD5-09, CD5-10,CD5-11,CD5- will be generated. 313 and CD5-315 15 If the operator proposes not to comply with a limitation N/A established in(d)of this section,an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • • iii u) a) C U a) 't E E w N o m 0a % a c a m c 0 o U C a) N o 3 Z 0 O co Cfl N C 0 O. O. C J a) 0. Q a --. • 7 N M 0 0 M O M T C0 G 7 7 7 (O "I- C C J a Q O f(O (n O) CO d co l CO (n U) CUC /- N N N N N cmE. • C UI NC.) 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O 0 2 (n a u .f c Ud o "a,_ N O 3 0 a)N .gip ZZZZZZZ .§-w� ▪ O _ 0 CD Q a a �� N O '- C U N O U a) 0 ),= x C N N m O c- 0 0 'i) O 2 2 0 V 0 d co O co O co O O.- ti 0 2 0 (n (n 4') u) (n (n (n(()V)(C) (Q(n N N 0 0 0 0 000000 _1 M o a 0 0 0 0 0 0 0 0 0 0 Z J • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 2.0-Jan'13 Well CD5-03 Assumptions Date 11/30/2015 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8"casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure(for wells on gas lift) 1,000 psi as) Maximum Fluid Density to avoid Burst of Surface Casing • C» P =PHydrostatic+P P burst85% Applied- Formation 4,429 =( 2,157* 0.052 *MWS )+ 1500 - ( 0.4337 * 2,157 ) N c> «w::: MWmax =— 34.4 ppg • Z2,157 TVD Surface Casing String Size 10.75 in TOC Est.@ 6,877' MD Weight 45.5 ppf A 4,205' TV b Grade L 80 rburst100% 5,210 psi M Stage Collar @ 4759'MD Pburst85% 4,429 psi Depth of Shoe 2,157 ft FIT/LOT @ Shoe 17.2 ppg or 1.929 psi FIT/LOT for Annulus 14.8 ppg CAMax Surf.Pressure 1,500 psi r ' TOC Est.@ 13,340' MD 7,130' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85%=PHydrostatic+PApplied-PGasGradient-PHeader 4,072 =( 7,130* 0.052 * M Wmax )+ 1,500 - ( 0.0700 * 7,130 ) - 1,000 Z X MWmax = 11 ppg 3.5"Tubing 2nd Casing String Size 7.625 in Z 7.399 TVD Weight 29.7 ppf Grade L 80 rcollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 7,130 ft Gas Gradient 0.07 psi/ft Max Surf.Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable=Shoe TVD Depth* .052 * Shoe FIT/LOT Pmax allowable= ( 2,157 *.052* 17.2 ) Pmax allowable= 1,929 psi This is the value for the Injection Permit"Maximum Anticipated Pressure at Shoe". • • 0 0 CN O Os ' p U). Z OJ 0 O O _Ln CN O N 3 _ 42) '.‘ O > _ o _O O 00 co0 N M Ca , —� A S) co T...• O O v1 II 'E1 Zt I 1 I 9- O a) 11 O Cn W a �0 1 o 1 11 II —aT) 1 1 I VJ O 1 in 1 O N ,1 1 , 1 1 , 11 ^ - I A1I 1 + Q I 1 , 1 j CD 1 X 1` O CII _ 1 1 1 ,—LO w ' C') _ ) I` 1 ' Nr �I '▪_ ' O 1 I I 1 v X I a) �� b O IC N 0 03 N o ,p_ HiQ O 1 1 Ma) 0 O = 1/ , , Ln O ;i , 14 v I 13 , O m o U = 6� M LCA •- 0 co so0 U Ln I o Lo s -Co r I O O O O O O 0 L() O LU Lo I (u!/l4sn 097) (+)upaoN/(-)u1noS N—. , • • . . . . . . • ( Tom and Shannon, • . , You.have requeSted to dipose of "oew-productd Olean up fluids from the. routine mixing Cf. tud and cement-at as as wll as the clean up fluids' resulting from • cleaning out the tanks ab the mud plant in preparation fr using oil base o The Commiseion had preVicuS1,11 aPPrOved disposing Of the new product'' clean up • fluids via annular dispoSal at CD 1 Due to the geological setting at Alpine, Class. 1 and Class 2 disposal options are • limited.. Phillips' prodeCessor, ARCO, hlimitation of ad ettablished the disPOOal . . optiont to pie CoMmiSSion's satisfaCtion andannular dianusalwas-apProved as the praCtical and wavironmental alternative. In these requests the waste fluids are no dit:terent than previously approved and . • are the result of the deVelooMent actiVities at Alpine. The COnmistioners have authori$d the to send you this mettage. By copy of this . email, Phillipe is authorized to dispose of otean up fluids as described in your email. . Please call w:Lth any 4Uestions. Tom Maunder, PE Sr. Petrdleum Engineer • . AOGCC ( 1P Env Coord wrote: . . :,. Dear 1 maunder, • > > Asnoted in the attached email, Tom Manson previously requested > tvathorAZat.ion to .dispose of new-product clean un fluids such. as cement > rinsate, and mudand brine pit rinses froM mixing operations via Annular > injection in psrndtte , wslls at the Alpine* CD2 Drill sits. A noted below, ▪ AOGCC Approved such disposal at the CDL Drill Site in. 1999, based on > integral relationship of the mud mixing facility and the on-site drilling > operation. > . > philliPS wOUld like to continuing puri ag this request. SfiCant 'clean • out of tanks at the mud mixing fadilftyfriust OcOutin.prepaxat)on .for the > temporary use of, oil based mud products At Alpine in thecoming menths, > The availability of annular disposal. as an option for tank. rinse fluids and > similar wastes would greatlyfacilitate this process. (Typically, routine > rinses are beneficially. reusecL however, there is p concern about the > potential quantity Of fluid thatcbuld be generated during thin large scale > clean up Process.) .›. > Tanks at the mud mixing facility stay contain either new and used mud > products. Though rinses in contact with used products may be injected in > the permitted olass. II disposal well (Cb19A) , rinees ,of new products would • potentially be routedto the plasSyl 4Sp9s4.well. (wp,-:02 , whets there is . > a difficulty managing solidS Content. The clatt 1 Well iS a critical > lifelino 'fbr fa&ilitY infT*Structure, being the dispasal location tor all > aolndttic effluent, and it is a priority to prevent any comproMise to this > disposal facility. Annular disposal Presents a preferred waste manageMent > alternatiVe in this case. ( > . I • • . • > Thank yan very Much for your ConsideratiOn of thiS requeet. Please do not > hesitate to contact nie at My alternate Via email or phone at (907) 670-4200 > if you have questions or need additional information. > Shannon Donnelly > Alpine FieldEnvirOnmental CoordinatOr > (907) 670-090 Forwarded by ALP Env Coord/PKO on. 11/02/01 1250 PINI. • > ALP Env Coord 08/.31/01 12;45 PN TO: toMjnacinderViadmtat,e,ak.ua . Subject: Request to inject Cement RimsaC-0 at CD2 Mt. Maunder, > InjeCtion of cement rLate and clean-up fluids from mud and brine mixing • oparations at the Alpine mud plant facility into approved annular disposal operations wasgrented bythe Aiaslc.a Oil- And Gas conservation Commission • ( OGCC) in the'March 17,' 109 letter from AOGCC to DOi ChesCer of ARCO > Alaska, InO. , now Phill.ipa Alaka, Inc.. (PAI) . 51-ie approval wail,' granted. to • FAI specifiCallfOr Alpine Drill site CD1 and authOrized Volumes up Co • > barrels through the annular soace. > PA,/ request that thisapproval be extended drilling operations at Alpine. > Drill Site P2. CementOpetations .fe›.r Aetting surface conduCtOrs > will be taking placeat the Grind :and Inject facility which is currently > attached to .0'0 drilling rig at .CD2 upon cOmPlet (4n of the cementing in > of the cOnductors, the lines and 'mixing' tank will have to be rinsed and the • rinsate dispased of. PAI request approval to inject t1 rinsata, and .7, other clean-up from the mud and brine mixing operations, into the annual • spaee of aPprov6d viells located at Drill Site CO2. >• IT yon have an .qUestions please contact me at 670-4200, > Tom Manson • Alpin Field Environmental Compliance rill torrumundenval • • i • CD5-03 Surface Casing Well: CD5-03 10-3/4"45.5#L-80 BTC-M& Hyd 563 Surface Casing Date: ConocoPhillips Rig: Doyon 19 L•• Alaska,Inc. Depth Jt Number JointsIF N A t Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 35.92 FMC 10-3/4" Casing Hanger .17 35.92 10-3/4", 45.5#, L-80, HYD563 Casing Pup, pin x pin 2.22 36.09 Jts 16 to 55 40 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 1710.31 38.31 XO 10-3/4", 45.5#, L-80, HYD563 Casing Box x 10-3/4" BTC-M Pin 42.75 1748.62 Jts 3 to 15 13 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 515.05 1791.37 10-3/4" HES Float Collar 1.20 2306.42 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 83.08 2307.62 10-3/4" Ray Oil Tools Silver Bullet Float Shoe 2.70 2390.70 2393.40 2393.40 2393.40 2393.40 2393.40 10 3/4" Shoe at 2,393' MD/2,157' TVD 2393.40 13 1/2" TD at 2,409' MD /2,166' TVD 15' rathole 2393.40 2393.40 2393.40 2393.40 2393.40 2393.40 2393.40 2393.40 1 Centek 10' up from shoe w/stop ring above on Jt#1 2393.40 1 Centek 30' up from pin w/stop ring above and below on Jt#2 2393.40 1 Centek 20' up from pin w/stop ring above on Jt#3 2393.40 1 Centek every joint from #4 to #54 Floating 2393.40 2393.40 No centralizer on last Jt 2393.40 Total Centralizers = 55 Centeks, 2393.40 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312TUR 2393.40 2393.40 2393.40 2393.40 2393.40 Remarks: Use Run &Seal pipe dope on BTC-M, Seal Guard ECF on HYD 563 Up Wt 140 K Avg MU Tq with Volant-7.7 k ft/lbs trq for BTC-M & 16.0 k ft/lbs trq for Hyd 563 Dn Wt 105 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:Rick Bjorhus/Dan Lowe • • Cement Detail Report 4' : . ‘ CD5-03 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/18/2015 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/21/2015 13:15 10/21/2015 16:03 CD5-03 Comment PJSM. Surface cement job: Dowell pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 75 bbls 11 ppg Mud Push II, Drop bottom plug, Dowell pump 26 bbls of 11.0 ppg Scavenger, 360 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm,225-460 psi.Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 3.3 bpm/390-180 psi. Drop top plug. Dowell pump 10 bbls H2O. Rig displace with 211.3 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 580 psi,decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min.Check floats- good. Full returns throughout 250 bbls good cement back to surface. Reciprocated pipe with 12'stroke until MudPush exited shoe.Stopped reciprocating due to excess drag and hole appearing to getting sticky.CIP at 16:03 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Returns to Surface 35.9 2,393.4 Yes 250.0 Yes Yes Q Pump Init(bbl/m...Q Pump Final (bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 500.0 1,000.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,297.0 Drill Bit 2,393.4 9 7/8 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 35.9 1,893.0 1,058 G 360.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 5.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,893.0 2,393.0 274 G 57.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/25/2015 a, Security Level: AK Development ._ °� • Daily Drilling Report 0 CD5-03 �c oPhitl ps Report Number: 4 Rig: DOYON 19 Report Date: 10/21/2015 Well Type AFE Typ Network/ID# - AFE+SuppAmt(Cost) Development ORIGINAL 10384855 12,224,659.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-03 ALPINE 2.88 4.0 0.00 2,326.0 2,326.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 10,506.22 115,003.99 397,976.22 1,284,422.21 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/18/2015 10/19/2015 37.00 36.30 0.70 11/23/2015 Last Casing String Surface,2,393.4ftKB Ops and Depth @ Morning Report 24hr Forecast Picking up and breaking in 5"DP,monitor annulus Continue to PU and breaking DP. Open annulus and check for flow. NU BOPE and MPD equip. Last 24hr Summary RU casing equipment and run 10-3/4"surface casing to 2,393'.Circ and condition mud, RU and pump cement and displace. Bump plug,check floats-good.Shut in and monitor annulus pressure. RU and PU/break in 5"high torque DP. General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 25°F/WC 11°F,NE20-G26 mph,VIS 7 mi, 55.0 Snow Supervisor. Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Our(hr) Phase Op.Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 00:45 0.75 SURFAC CASING BHAH P 88.0 0.0 Continue to LD BHA from 88'. 00:45 01:30 0.75 SURFAC CASING BHAH P 0.0 0.0 Clean and clear floor.RD 5"DP elevators.PU casing tools and equipment. 01:30 02:30 1.00 SURFAC CASING RURD P 0.0 0.0 RU Volant CRT tool.RU 4'bail extensions and 10-3/4"elevators. RU casing tools.MU floor valve on XO. 02:30 09:45 7.25 SURFAC CASING PUTB P 0.0 2,393.0 PJSM. Run 10-3/4"Silver Bullet float shoe,2 jts 10-3/4"BTCM casing,HES float collar,2 jts 10 3/4"BTC casing.Baker-Lok first 3 connections.Check floats-okay. Continue running 10-3/4",45.5 lb/ft, L-80, BTCM, R3 casing to 602'(15 jts including shoe track). Install 42.75'BTCM x H563 XO joint followed by 40 joints 10-3/4", 45.5 lb/ft, L-80, H563,R3 to 2,393.4'md. Avg MU torque= 7,700 ft-lb for BTCM when made up to the mark using Run&Seal thread dope, 16,000 ft-lb torque for H563 connections with Seal Guard ECF thread dope. PU= 140K,SO=105K Cents(Centek-10-3/4"bow springs,55 total): 1 -10'from shoe on stop collar, 1 -30'from pin on jt #2 on stop, 1 -20'from pin on jt #3, 1 -free floating on joints#4- 54 09:45 10:15 0.50 SURFAC CEMENT RURD P 2,393.0 2,393.0 BD Top drive and RU cement lines to Volant tool/cement swivel. Latest BOP Test Data Date I Com Page 1/4 Report Printed: 11/25/2015 Security Level: AK Development • Daily Drilling Report y +�l CD5-03 ���ips Report Number: 4 ConoX.irrk:.s Rig: DOYON 19 Report Date: 10/21/2015 Time Log Time ; Start Depth Start Time.. End Time Our(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 10:15 13:15 3.00 SURFAC CEMENT CIRC P 2,328.0 2,328.0 Circ&cond mud for cement job Stage flow rate from 1-4.5 bpm, 320-330 psi bpm,reciprocate pipe 12'. (SIMOPs-RD casing tools and equipment.RD 4'bail extensions, 10.75"elevators for TD and LD.Clean&clear floor. 13:15 16:15 3.00 SURFAC CEMENT CMNT P 2,328.0 2,328.0 PJSM. Surface cement job: Dowell pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 75 bbls 11 ppg Mud Push II,Drop bottom plug,Dowell pump 26 bbls of 11.0 ppg Scavenger,360 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm,225-460 psi.Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx-iail cement at 3.3 bpm/390- 180 psi.Drop top plug.Dowell pump 10 bbls H2O.Rig displace with 211.3 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 580 psi, decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min.Check floats-good.Full returns throughout 250 bbls good cement back to surface.R ciprocated pipe with 12'stroke until MudPush exited shoe.Stopped reciprocating due to excess drag and hole appearing to getting sticky.CIP at 16:03 hrs. 16:15 16:30 0.25 SURFAC CEMENT RURD P 0.0 0.0 Flush surface riser and Annular with black water. Shut in annular and monitor annulus pressure. Check pressure every 10 min for one hour and every 30 min there after.Pressure= 11 -12 psi 16:30 18:00 1.50 SURFAC CEMENT RURD P 0.0 0.0 BD and RD cement lines.RD Volant CRT.Clear and clean rig floor. 18:00 18:30 0.50 SURFAC CEMENT PULD P 0.0 0.0 PJSM. PU 5"DS50 Hi-Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC. 18:30 19:15 0.75 SURFAC CEMENT SVRG P 0.0 0.0 Service Rig:Top drive, drawworks, Iron roughneck and pipe skate. 19:15 00:00 4.75 SURFAC CEMENT PULD P 0.0 0.0 PJSM. PU 13 stands of 5"DS50 Hi-Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC. Page 2/4 Report Printed: 11/25/2015 \s, • Security Level: AK Development °u', Daily Drilling Report k IFX '3111k. t,", -- CD5-03 CcioeciPhiCli�xs Report Number: 4 Rig: DOYON 19 Report Date: 10/21/2015 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gap Vis(s/qt) PV Calc(cP) (Ibf/10011') (Ibf/10011') (Ibf/10011') (Ibf/10011') MBT(Ib/bbl) (mLl30min) pH ("F) (%) DRILPLEX 2,409.0 10.00 18.0 4.0 2.0 3.0 4.000 10.0 9.9 69.0 DRILPLEX 2,409.0 10.00 16.0 19.0 10.0 13.0 13.000 10.0 9.8 66.0 Injection Fluid Fluid Source From Lease(bbl) _ Dest Vendor Manifest Number Note Cementing Fluids 275.0 CD1-01 AES 35500 CD5-03 Source Well Drilling Mud WBM 275.0 CD1-01 AES 35496 CD5-03 Source Well Drilling Mud WBM 250.0 CD1-01 AES 35497 CD5-03 Source Well Drilling Mud WBM 225.0 CD1-01 AES 35498 CD5-03 Source Well Drilling Mud WBM 50.0 CD1-01 AES 35499 CD5-03 Source Well Drill Strings: BHA No.1 - Surface / Bit Run No. 1 - 13 lain,VM-3,5255724 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/321 IADC Bit Dull String Wt(1000lbf) 115.0 2,409.0 0.76 16/16/16/15 1-2-BU-A-E-I-PN-TD 35 Drill String Components „ts Item Des OD(in) ID(in) Top Conn Sz(in) °, Top Thread Cum:Len(ft) Drill Pipe 5 4.276 4 1/2 IF 1,664.47 6 5"HWDP x6 5 3.000 4 1/2 IF 2,213.47 1 Drilling Jars-Mechanical 7 3/4 2.750 4 1/2 IF 2,248.02 7-7/8"Saver Sub 7 1/4 4 1/2 IF 2,251.12 1 8"Flex NMDC 8 2.880 6 5/8 Reg 2,281.56 12 1/8"NM Stabilizer 12 1/8 2.880 6 5/8 Reg 2,289.65 1 8 1/4"NMDC 8 1/4 2.875 6 5/8 Reg 2,320.69 8 1/4"NM UBHO 8 1/4 2.813 6 5/8 Reg 2,322.71 8 1/4"MWD 8 1/4 5.109 6 5/8 FH 2,350.41 NM Crossover 8 2.880 6 5/8 REG 2,351.93 1 Pony Drill Collar 8 2.813 6 5/8 Reg 2,361.96 1 Pony Drill Collar 8 2.813 6 5/8 Reg 2,371.99 12 1/8"NM Stabilizer 13 3/8 2.880 6 5/8 Reg 2,380.09 A962M3445SP PowerPak 9 5/16 2.125 6 5/8 Reg 2,409.00 Drilling Parameters Flow Rate Cum Drill Time Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) End Depth(ftKB) Cum Depth(ft) (hr) Time(hr) (gpm) (1000lbf) (rpm) SPP(psi) (10001bf) (1000Ibf) (10001bf) Off Btm Tq ;Drill Tq 2,326.0 2,409.0 2,294.00 22.39 0.63 785 30 60 2,330.0 120 122 110 2,700.0 6,200.0 2,409.0 2,409.0 2,294.00 22.39 Wellbores Wellbore Name Wellbore API/UWI CD5-03 501032071800 Section Des Size(in) Act Top(ftKB) " Act Btm(ftKB) Start Date End Date COND 42 35.9 115.0 3/9/2015 3/9/2015 SURFAC 13 1/2 115.0 2,409.0 10/18/2015 10/23/2015 I NTRM 1 11 2,409.0 14,350.0 10/23/2015 11/5/2015 PROD1 6 1/2 14,350.0 20,999.0 11/5/2015 11/13/2015 Casing Strings Csg Des Run Date OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Corn Surface 10/21/2015 10 3/4 45.50 L-80 2,393.4 Centek,SI), 10-3/4"x 13-1/2",PN 1034-1312TUR Cement Surface Casing Cement -Started @ 10/21/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-03 Surface,2,393.4ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 35.9 2,393.4 3 500.0 Page 3/4 Report Printed: 11/25/2015 • Security Level: AK Development Daily Drilling Report CD5-03 Report Number: 4 CormooPhillips Rig: DOYON 19 Report Date: 10/21/2015 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal)"' Yield(fE/sack) Est Top(EKB) Est.Btm.(ftKB) Lead Cement G 1,058 360.0 11.00 1.91 35.9 1,893.0 Tail Cement G 274 57.0 15.80 1.17 1,893.0 2,393.0 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR Other 1 Dan COMPANY ENGINEER ConocoPhillips Company Rig Engineer SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks, housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Hughes SERVICE ENGINEER-MPD SolstenXP 1 Clay SERVICE ENGINEER-Gyro Halliburton Energy Services Inc. (HES) OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm WELLSITE GEOLOGIST Other Waters Petroleum CASING/TUBING Doyon Drilling Inc SERVICE ENGINEER Camco MWD Gyrodata Inc. SERVICE ENGINEER Weatherford 1 MPD Doyon Drilling Inc 1 Mark-Doyon Casing Page 4/4 Report Printed: 11/25/2015 • Security Level: AK Development Daily Drilling Report %f CD5-03 > cciPhjllps Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2015 Well Type r AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10384855 12,224,659.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) ALPINE 3.88 5.0 0.00 2,409.0 2,409.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 4,408.86 119,412.85 176,149.42 1,460,571.63 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/18/2015 10/19/2015 37.00 32.64 4.36 11/20/2015 Last Casing String Surface,2,393.4ftKB Ops and Depth @ Morning Report 24hr Forecast Set MPD test plug in rotating head and test Continue testing BOPE and MPDE.PU 9-7/8"x 11"BHA#2,RIH, test casing to 3,500 psi,drill out cmt shoe track and 20'of new fm, displace to 9.6 ppg LSND mud, perform LOT,drill intermediate hole section. Last 24hr Summary Continue to PU and breaking DP. Open annulus and check for flow-static. NU BOPE and perform Between Well Maint. NU new MPD equip. RU to test BOPE General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 26°F/WC 10°F,E22 mph,VIS 10 mi,Overcast 56.0 BOP test witnessed by Chuck Scheve of the AOGCC. Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 08:00 8.00 SURFAC CEMENT PULD P 0.0 0.0 PJSM. PU 34 stands of 5"DS50 Hi-Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC(47 total). Note:Pressure on annulus-11 psi at 08:00 hrs.Bled off pressure and open bag.No flow or drips observed. 08:00 08:15 0.25 SURFAC CEMENT OWFF P 0.0 0.0 Flo-chk-static. PJSM for ND riser 08:15 09:00 0.75 SURFAC CEMENT RURD P 0.0 0.0 Backout and LD landing joint. SIMOPs-Perform BWM on lower pipe rams. 09:00 11:30 2.50 SURFAC CEMENT NUND P 0.0 0.0 ND riser,flow line,and drain,ND 20"annular, 11:30 12:15 0.75 SURFAC CEMENT NUND P 0.0 0.0 Split starting head and remove flange. Remove slip segments from conductor. 12:15 12:45 0.50 SURFAC CEMENT NUND P 0.0 0.0 Raise rear wind walls and remove annular and starting head from cellar.Bring in new RCD head and controller. 12:45 13:30 0.75 SURFAC WHDBOP NUND P 0.0 0.0 Install speed head and test metal to metal seals to 1,000 psi for 30 min-good.PJSM for NU. 13:30 15:00 1.50 SURFAC WHDBOP MPDA T Non-rig Other 0.0 0.0 NU BOPE. Remove old RCD and Surface Auxilliary dutch flange for change out. Eqp Eq. Latest BOP Test Data Date I Com Page 1/3 Report Printed: 11/25/2015 • Security Level: AK Development Daily Drilling Report a CD5-03 Gatto0DPhitlips Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2015 Time Log Time Start.Depth Start Time End.Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 15:00 16:00 1.00 SURFAC WHDBOP SVRG P 0.0 0.0 Perform BWM(between wells maintenance)on BOPE.Open ram doors&inspect. 16:00 21:00 5.00 SURFAC WHDBOP MPDA T Non-rig Other 0.0 0.0 NU new RCD head,MPD Orbit Surface Auxilliary and 2"valve assembly, 1502 Eqp Eq. union valves,control box, KetchCan and drain hoses. Measure stack component RKB distances. Attempt to install trip nipple,appeared short and called out welder. 21:00 22:45 1.75 SURFAC WHDBOP RURD P 0.0 0.0 Line up to test BOPE. PU, install 5"test joint and test plug. Fill lines and stack with H2O. 22:45 23:30 0.75 SURFAC WHDBOP MPDA T Non-rig Other 0.0 0.0 Continue to RU new Trip nipple, Surface Auxilliary flow line,hole fill and bleed off Eqp Eq. line.Center stack. 23:30 00:00 0.50 SURFAC WHDBOP BOPE P 0.0 0.0 Test BOPE with 5"test jts-Test Annular and HCR choke/kill 250/2,500 psi and chart for 10 min. Upper 3-1/2"x 6"VBR's, blind rams,Auto IBOP, (Choke valves#1, 12, 14)-14, HCR choke/kill,Demco on Kill, to 250/3500 psi for 10 min.Testing witnessed by Chuck Scheve of the AOGCC. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr, Type Depth(ftKB) Dens(lb/gal) Vs(s/qt) PV Calc(cP) (Ibf/100ft") (Ibf/100fF) ,(Ibf/100fF) )' (tbf/100f9 i MBT(Ib/bbl) (mU30min) pH ('F) (%) DRILPLEX 2,409.0 10.00 18.0 9.0 3.0 5.0 6.000 10.0 10.3 62.0 DRILPLEX 2,409.0 10.00 17.0 9.0 2.0 4.0 5.000 10.0 10.3 66.0 Injection Fluid Fluid Source +'From Lease(bbl) Dest Vendor Manifest Number Note Cementing Fluids 250.0 CD1-01 AES 35501 CD5-03 Source Well Cementing Fluids 250.0 CD1-01 AES 35502 CD5-03 Source Well Cementing Fluids 250.0 CD1-01 AES 35503 CD5-03 Source Well Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR Other 1 Dan COMPANY ENGINEER ConocoPhillips Company Rig Engineer SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Hughes SERVICE ENGINEER-MPD SolstenXP 1 Clay Page 2/3 Report Printed: 11/25/2015 • Security Level: AK Development ADaily D •rilling Report ,',:',-,.0 ' ', , - „ ,,_ CD5-03 ConornPhiCl ps Y, Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2015 Head Count/Manhours Function Company Name Count Note SERVICE ENGINEER-Gyro Halliburton Energy Services Inc. (HES) OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm WELLSITE GEOLOGIST Other Waters Petroleum CASING/TUBING Doyon Drilling Inc SERVICE ENGINEER Camco MWD Gyrodata Inc. SERVICE ENGINEER Weatherford 3 MPD Page 3/3 Report Printed: 11/25/2015 O O O 0 0 0 0 0 0 O 0 0 0 O O U) O U) N CO CO 00 I,- CD Liz ,t M N r r o) O) CO N- I"- CO 'N O) MM N.- N- N- N- - r- I` r- NCOCDCOCDCOCD YU) y aa)) •.C,_. mm x i CO c s_ - 0 Ln 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p 73 x E- C E ,. 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CD5-03 Intermediate Casing Well: CD5-03 ConocoPhillips 7-5/8", 39 & 29.7#, TN110 & L-80, BTC-M & Hyd 563, Casing Date: 11/1/2015 Alaska,Inc. Rig: Doyon 19 Depth Jt Number of Jts Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.40,y FMC 7.625" fluted hanger .4 34.40 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.08 34.44 Jts 295 to 339 45 Jts 7-5/8", 29.7#, L-80 H563 Casing Dopeless 1805.28 36.52 7-5/8", 29.7#, L80 XO jt , H563 DPLS box X BTC pin 39.35 1841.80 Jts 174 to 294 121 Jts 7-5/8", 29.7#, L80, BTC-M Casing 5096.09 1881.15 7-5/8", HES-II Cementer (Stage Collar) (Qannik Btm @ 6,472') 3.03 6977.24 Jts 19 to 173 155 Jts 7-5/8", 29.7#, L80, BTC-M Casing 6543.49 6980.27 7-5/8", 39#, TN110 XO jt, BTC-M box X HYD 563 pin 41.81 13523.76 Jts 4 to 18 15 Jts 7-5/8", 39#, TN110, HYD 563 Casing 638.87 13565.57 7-5/8", 39#, P110, HYD 563, Halliburton Baffle Adapter Collar 1.37 14204.44 Jts 3 to 3 1 Jts 7-5/8", 39#, TN110, HYD 563 Casing 42.79 14205.81 7-5/8", 39#, C110, HYD 563 Hailliburton Float Collar w/By-pass Adaptor 1.59 14248.60 Jts 1 to 2 2 Jts 7-5/8", 39#, TN110, HYD 563 Casing 87.66 14250.19 7-5/8", 39#,C110, HYD 563 Halliburton Float Shoe 2.80 14337.85 1040.64 14340.65 14340.65 14340.65 14340.65 TD 9-7/8" Hole at 14,350' MD/ 7,399' TVD (11" Hole to 14,254") 14340.65 Casing Shoe 14,340.65' MD/7,399' TVD 14340.65 14340.65 1 Centek 10' up from shoe w/stop rings on Jt#1 14340.65 1 Centek 30' up from pin w/stop rings on Jt#2  14340.65 1 Centek on every joint, floating from #4 to#198 14340.65 1 Centek on every joint, floating from #282-#284 14340.65 Straight Blade Centralizer on every other joint from #286-#334 14340.65 14340.65 14340.65 Total Cents = Centek = 202 /Straight Blade = 24 14340.65 14340.65 Total 349 Joints in Pipe Shed 14340.65 8 BTC-M & 2 DPLS left in shed 14340.65 14340.65 Remarks: Run-n-Seal on BTC-M, Seal Guard on HYD563 Up Wt 500 K 6,800ft/Ibs BTC-M, 12,400ft/lbs HYD563 Dopeless, Dn Wt 60 K 19,300ft/lbs on 39#HYD563 Block Wt 60 K Rig Supervisors:Rick Bjorhus/Adam Dorr/Tom Polacek . • Cement Detail Report CD5-03 ConocoPhitiips String: Intermediate 2 Stage Cement Job: DRILLING SUPPORT-CAPITAL, 10/27/20... Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 2 Stage Cement 11/1/2015 16:15 11/2/2015 00:15 CD5-03 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate 1st Stage Cement 7 5/8"Shoe 13,340.0 14,340.7 No Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final (bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 320.0 850.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment No Returns Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 13,340.0 14,340.7 424 G 87.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 1.16 5.07 15.80 4.75 500.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate 2nd Stage Iscolate Qaanik formation 6,877.0 6,977.0 No No Yes Cement Q Pump mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 200.0 2,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment No Returns Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 6,877.0 6,977.0 441 G 91.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/25/2015 Security Level: AK Development • • Daily Drilling Report -t CD5-03 ConocoPhillips Report Number: 15 Rig: DOYON 19 Report Date: 11/1/2015 Well Type AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10384855 12,224,659.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-03 ALPINE 13.88 15.0 0.00 14,350.0 14,350.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 30,563.44 827,419.67 897,750.03 5,619,722.77 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/18/2015 10/19/2015 37.00 31.63 5.37 11/19/2015 Last Casing String Intermediate, 14,340.7ftKB Ops and Depth @ Morning Report 24hr Forecast Cut&Slip Drill Line Cont.to displace 2nd stage cement&close stage collar.Set pack off&test. R/D Volant.Cut&slip drill line.L/D 5"DP Last 24hr Summary Cont.to RIH with 7-5/8"casing and land on hanger @ 14,340'.Cement 1st stage cement job. Pump 2nd stage cement job&displacing cement @ 24:00 hrs General Remarks Weather Head Count No AIS. Rig&Camp on high line power. 12°F/WC-7°F,E 21 mph,VIS 7 mi,Light 59.0 Snow Supervisor _ Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Weifeng Dai Drilling Engineer Tom Polasek Rig Engineer Time Log Time' Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (555) End Depth(ftKB) Operation 00:00 14:30 14.50 INTRM1 CASING PUTB P 11,231.0 14,340.0 Cont.to RIH with 7-5/8" Intermediate casing from 11,231' to 14,167'. Lost returns at 12,430'and gained 20klbs in down weight.Town support notified and continued to RIH. Started to take weight at 14,166'(Transition from the B3 to B1)momentarily detained. Worked pipe up to 500k cycling do to 50k made 4'.Establish circulation and work up to 2bpm 800psi while working pipe.Start to incur losses and slow pumps to 1.5bpm 530psi.Continue working pipe and downward movement regained and circulation lost/hole packed off.Work pipe to release pack-off and continue to work pipe down pulling up to 400k and slacking off to 50k. Continue to RIH with 7-5/8"casing and pick up and land hanger on depth at14,340'. Only 1'of upward movement obtained while working pipe at original tight spot at 14,167' Land out hanger with 125k down. Blocks 60klbs 14:30 15:15 0.75 INTRM1 CEMENT CIRC P 14,340.0 14,340.0 Attempt to re-establish circulation. Start at 1/2bpm with no returns. Pump a total of 25bbls worked rate up to 6bpm at 810psi injection rate. No returns. Latest BOP Test Data DateDom I 10/23/2015 Test ROPF with 5"test its-Test Annular and HCR choke/kill 250/2 500 nsi and chart for 5 min lJnner 3-1/2"x A"VRR's blind ram Page 1/3 Report Printed: 11/25/2015 \ SecurityLevel: AK Development " � ' • Daily Drilling Report p CD5-03 G011000"hittips Report Number: 15 Rig: DOYON 19 Report Date: 11/1/2015 Time Log Time Start Depth Start Time End Time,.:. Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class `"(ftKB) End Depth(ftKB) Operation 15:15 16:15 1.00 INTRM1 CEMENT RURD P 14,340.0 14,340.0 Rig down elevators and spiders. Clean and clear rig floor of casing running tools in preparation for cement job.PJSM on cement job 16:15 19:30 3.25 INTRM1 CEMENT CMNT P 14,340.0 14,340.0 Dowell pump 1.5 bbls H2O and pressure test lines to 3,500 psi (good),40.1 bbls 12.0 ppg Mud Push,Drop bypass plug,Pump 87.7 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40% excess), Drop top plug. Dowell displace w/10.1 bbls H2O. Rig displace w/640 bbls 11.1 ppg LSND. Bump plug @ 6420 stks, w/3 bpm @ 320 psi.Pressure up to 850 psi&hold for 5 min.Check floats good.CIP @ 19:21 hrs. No reciprocation&no returns. 19:30 20:00 0.50 INTRM1 CEMENT CIRC P 6,997.0 6,997.0 Open stage collar @ 6,997' w/3300 psi @ 2 bpm.Establish circ w/2bpm @ 350 psi,stage rate to 3 bpm @ 470 psi,stage rate to 4 bpm n@ 520 psi. Lose circulation. 20:00 21:15 1.25 INTRM1 CEMENT CMNT P 6,997.0 6,997.0 PJSM on 2nd stage cement. Discuss plan forward with towm. SIMOPS-Clean&clear floor of BHA tools&equipment. 21:15 00:00 2.75 INTRM1 CEMENT CMNT P 6,997.0 6,997.0 Dowell pump 1.5 bbls H2O and pressure test lines to 3,500 psi (good),40.1 bbls 12.0 ppg Mud Push,91.2 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement (40%excess),Drop closing plug. Dowell displace w/10.1 bbls H2O. Rig displace w/241 bbls 11.1 ppg LSND w/3 bpm @ 170 psi. No returns Total formation losses for past 24 hrs=1828 bbls Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP); (lbf/100fr) (IbK900fr) (Ibf/100fr) (Ibf/100fti MBT(Ib/bbl) (mL/30min) pH (CF) (%) LSND 14,350.0 11.10 45 14.0 20.0 7.0 9.0 11.000 15.0 9.7 76.0 LSND 14,350.0 11.10 45 13.0 24.0 9.0 11.0 12.000 15.0 9.8 74.0 Wellbores Wellbore Name Wellbore API/UWI C05-03 501032071800 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) ,:Start Date V End Date COND 42 35.9 115.0 3/9/2015 3/9/2015 SURFAC 13 1/2 115.0 2,409.0 10/18/2015 10/23/2015 INTRM1 11 2,409.0 14,350.0 10/23/2015 11/5/2015 PROD1 6 1/2 14,350.0 20,999.0 11/5/2015 11/13/2015 Page 2/3 Report Printed: 11/25/2015 Security Level: AK Development Daily Drilling Report CD5-03 illipsr Report Number: 15 ConocoPh Rig: DOYON 19 Report Date: 11/1/2015 Casing Strings Csg Des :Run Date OD(in) Wt/Len(Ib/ft) Grade Set Depth(ftKB) Corn Intermediate 11/1/2015 7 5/8 29.70 L80 14,340.7 202 Centek&24 Aluminum Straight Blade Cement Intermediate 2 Stage Cement -Started @ 11/1/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-03 Intermediate, 14,340.7ftKB No returns during cementing operations Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate 1st Stage Cement 13,340.0 14,340.7 3 320.0 Fluid : Class Amount(sacks) .Vol Pumped(bbl) Dens(lb/gal) Yield(ft/sack) .. Est Top(ftKB) Est Btm(ftKB) Lead Cement G 424 87.7 15.80 1.16 13,340.0 14,340.7 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate 2nd Stage Cement 6,877.0 6,977.0 3 200.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Lead Cement G 441 91.2 15.80 1.16 6,877.0 6,977.0 Head Count/Manhours Function Company; Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR SolstenXP 1 Adam COMPANY ENGINEER ConocoPhillips Company 2 Rig Engineer-Tom/Sara SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger 1 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Hughes SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Halliburton Energy Services Inc. 1 Cementer (HES) OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm WELLSITE GEOLOGIST Other Waters Petroleum CASING/TUBING Doyon Drilling Inc 1 1 @ CD1 SERVICE ENGINEER Cameo SERVICE ENGINEER Schlumberger 1 Rhino Reamer Page 3/3 Report Printed: 11/25/2015 Security Level: AK Development Daily Drilling Report 'Et('-'4fttfIttii,II CD5-03 ecaPtaillps Report Number: 16 Rig: DOYON 19 Report Date: 11/2/2015 Well Type i,. AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10384855 12,224,659.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-03 ALPINE 14.88 16.0 0.00 14,350.0 14,350.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 23,078.95 850,498.62 424,524.43 6,044,247.20 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/18/2015 10/19/2015 37.00 31.63 5.37 11/19/2015 Last Casing String Intermediate, 14,340.7ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE UD 5"DP.Test BOPE.M/U BHA#3&RIH while picking up 4"DP Last 24hr Summary Cont.to displace 2nd stage cement&close stage collar.Set pack off&test. R/D Volant. Cut&slip drill line. Remeove RCD bearings. L/D 5"DP General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 16°F/WC 2°F,E 13 mph,VIS 10 mi,Clear- 55.0 OA @ 100 psi Fog AM Supervisor::: Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Weifeng Dai Drilling Engineer Tom Polasek Rig Engineer Time Log Time Start Depth Start Time End Time Dur(hr) :.. Phase - Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 00:30 0.50 INTRM1 CEMENT CMNT P 6,997.0 6,997.0 Rig displace w/69 bbls 11.1 ppg LSND w/3 bpm @ 200 psi.Bump plug 3065 stks.Pressure up to 1100 psi&close stage collar, continue to 2200 psi&hod for 5 min.Bleed off&check floats (good)No returns 00:30 01:30 1.00 INTRM1 CEMENT OWFF P 0.0 0.0 F/C.annulus appear to be dropping,floats holding&casing full. Un-sting Volant from landing jt &line up to monitor annulus on nTT.Static losses @ 18 bbls/hr 01:30 03:45 2.25 INTRMI CEMENT WWSP P 0.0 0.0 Back out landing jt&UD same. Pull wear ring.Set pack off w/5 k wob&RILDS.Test pack off to 5000 psi(good) 03:45 05:15 1.50 INTRM1 CEMENT RURD P 0.0 0.0 R/D Volant casing tools& equipment.R/U 5"elevators. 05:15 06:00 0.75 INTRM1 CEMENT WWWH P 0.0 0.0 M/U stack washer&flush stack. 06:00 07:30 1.50 INTRM1 CEMENT SLPC P 0.0 0.0 Slip&cut 60'drill line. Re-calibrate block height. 07:30 08:00 0.50 INTRM1 'CEMENT SVRG P 0.0 0.0 Service rig,top drive&blocks 08:00 09:15 1.25 INTRM1 CEMENT MPDA P 0.0 0.0 Strip off of DP 2 MPD bearings used to drill intermediate section. Clear floor of MPD tools&equip. 09:15 00:00 14.75 INTRM1 CEMENT PULD P 0.0 0.0 UD 372 jts 5"DP from derrick via 90'mouse hole.(SIMOPS @ 11:00 hrs Annular disposal injectivity test,water flush&freeze protect on 10 3/4"X 7 5/8"annulus) Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr_ Type I Depth(ftKB). Dens(Ib/gal) Vis(s/q€) PV Calc(cP) (Ibf/100fF) (Ibf/100fF) (Ibf/100fF) (lbf/100W) MBT(lb/bbl) (ml/30min)'.: pH (°F) (X) LSND 14,350.0 11.10 40 9.0 17.0 5.0 7.0 8.000 6.3 10.0 53.0 Latest BOP Test Data Date I Com 10/23/2015 Test ROPE with 5"test its-Test Annular and HCR choke/kill 250/2 500 nsi and chart for 5 min Unner 3-1/2"x 6"VBR's blind ram Page 1/2 Report Printed: 11/25/2015 Security Level: AK Development • Daily Drilling Report ` ...., CD5-03 Co coF"tai11 Report Number: 16 Rig: DOYON 19 Report Date: 11/2/2015 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp, Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') :(lbf/100tV) :(Ibf/100fV) ; (Ibf/100ft2) MBT(Ib/bbl) (mU3Omin) pH (°F) (%) LSND 14,350.0 11.10 42 10.0 19.0 6.0 7.0 8.000 6.9 10.0 58.0 Injection Fluid Fluid Source From Lease(bbl) Dest +: Vendor Manifest Number Note Diesel 86.0 CD5-03 Freeze Protect OA Drilling Mud WBM CD5-03 275.0 CD1-01 AES 35552 CD5-03 Source Well Drilling Mud WBM CD5-03 275.0 CD1-01 AES 35551 CD5-03 Source Well Drilling Mud WBM CD5-03 14.0 CD5-03 Injectivity Test for AD Fresh Water 300.0 CD5-03 H2O Flush Wellbores Wellbore Name Wellbore API/UWI CD5-03 501032071800 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) .:::Start Date End Date COND 42 35.9 115.0 3/9/2015 3/9/2015 SURFAC 13 1/2 115.0 2,409.0 10/18/2015 10/23/2015 I NTRM 1 11 2,409.0 14,350.0 10/23/2015 11/5/2015 PROD1 6 1/2 14,350.0 20,999.0 11/5/2015 11/13/2015 Head Count/Manhours Function _ Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR SolstenXP 1 Adam COMPANY ENGINEER ConocoPhillips Company 2 Rig Engineer-Tom/Sara SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Hughes SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Halliburton Energy Services Inc. (HES) OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm WELLSITE GEOLOGIST Other Waters Petroleum CASING/TUBING Doyon Drilling Inc SERVICE ENGINEER Camco SERVICE ENGINEER Schlumberger Page 2/2 Report Printed: 11/25/2015 Security Level: AK Development Daily Drilling Report CD5-03 P[ illips Report Number: 17 Rig: DOYON 19 Report Date: 11/3/2015 Well Type AFE Typ Network/ID# AFE*Supp Amt(Cost) Development ORIGINAL 10384855 12,224,659.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-03 ALPINE 15.88 17.0 0.00 14,350.0 14,350.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 4,172.30 854,670.92 171,335.53 6,215,582.73 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/18/2015 10/19/2015 37.00 31.63 5.37 11/19/2015 Last Casing String Intermediate, 14,340.7ftKB Ops and Depth @ Morning Report 24hr Forecast Drilling Stage Collar @ 6,977' RIH w/BHA#3 on 4"DP&drill out. FIT to 13.0 ppg.Displace to FloPro. Drill ahead. Last 24hr Summary L/D 5"DP from derrick. R/U&test BOPE.C/O saver sub on top drive.M/U 6 1/2"BHA#3. RIH to 5,185" General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 24°F/WC 14°F,S 9 mph,VIS 10 mi,Cloudy 54.0 OA @ 250 psi Supervisor '... Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Weifeng Dai Drilling Engineer Tom Polasek Rig Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code "Activity Code P-T-X Trbl Code Trbl Class (ftKB): End Depth(EKE) Operation 00:00 00:45 0.75 INTRM1 CEMENT PULD P 0.0 0.0 L/D 18 jts 5"DP from derrick via 90'mouse hole 00:45 03:00 2.25 INTRM1 WHDBOP RURD P 0.0 0.0 L/D 5"handling equipment. Bring to rig floor XT39 FOSV&Dart valves. Prep for BOPE test,. FMC set upper test plug. Fill stack w/H20&R/U to test BOPE. 03:00 10:00 7.00 INTRM1 WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 3,4&4 1/2" test joints,Test Annular to 250/2,500 psi for 10 min,Test choke valves#1 -14 and needle valve to 250/3,500 psi for 10 min. HCR Choke and Kill,4"Demco,4" FOSV,dart&needle valves, HCR choke&kill,3 1/2"X 6"upper& lower VBR's,&blind rams to 250/3500 psi for 10 min.-good. Koomey test; IP=3,100 psi, manifold press after close=1,500 psi,200 psi recovery 36 sec,full recovery 222 sec, N2-4 bottle average=1990 psi.Tested gas alarms.Draw down on man& super choke to 1,100 psi. - Test witnessing waived by Bob Noble of the AOGCC. 10:00 10:30 0.50 INTRM1 WHDBOP RURD P 0.0 0.0 B/D choke manifold&kill lines. R/D testing equipment.Pull upper test plug.Install split bushings. 10:30 14:30 4.00 INTRM1 CEMENT RURD P 0.0 0.0 C/O saver sub to XT 39.C/O elevators to 4". Install skate roller. Install 7.0625 ID wear ring.Adjust air boot on trip nipple.SIMOPS- Bring BHA tools&equip to rig floor. Latest BOP Test Data Date I Com 11/3/2015 ROPF Test Test with 3 1/2 4&4 1/2"test mints Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 -14 and needle valv Page 1/3 Report Printed: 11/25/2015 Security Level: AK Development • Daily Drilling Report CD5-03 ConocoPhillips Report Number: 17 Rig: DOYON 19 Report Date: 11/3/2015 Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbi Class (ftKB) End Depth(ftKB) _ 'Operation 14:30 17:15 2.75 INTRM1 CEMENT BHAH P 0.0 371.0 M/U BHA#3 as per SLB to 371' 17:15 00:00 6.75 INTRM1 CEMENT PULD P 371.0 5,185.0 RIH w/BHA#3 while single in hole with 4"DP from pipe shed f/371'to 5,185' Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (lbf/100th) (Ibf/1 o0ft') (Ibf/100ft') (lbff100fP) MBT(Ib/bbl) (mL/30fiin) pH (T) (9/.) LSND 14,350.0 11.10 45 11.0 16.0 6.0 7.0 8.000 6.3 9.8 46.0 LSND 14,350.0 11.10 39 10.0 20.0 6.0 7.0 8.000 6.3 9.3 51.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-03 275.0 CD1-01 AES 35553 CD5-03 Source Well Drill Strings: BHA No.3 - Production / Bit Run No. 3 - 6 1/2in,MDI513,`JH8923 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 14,350.0 18,768.0 0.46 11/11/11/11/11 0-1-CT-G-X-I-NO-DTF 309 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) PowerDrive X6 5 2.250 35 NC 22.54 Periscope-LWD(Dir&Logging) 4 5/8 2.125 35 NC 47.41 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 81.26 NM Stab(NPFV-plunger) 4 13/16 2.313 3 1/2 IF 87.57 Steel Float Sub w/NPFV-plunger 4 3/4 2.375 3 1/2 IF 90.59 1 Non Mag Flex Collar 4 13/16 2.250 3 1/2 IF 120.21 1 Non Mag Flex Collar 5 1/16 2.250 3 1/2 IF 150.17 1 Non Mag Flex Collar 5 1/16 2.250 3 1/2 IF 180.97 XO-XT39 Box x 3.51F Pin 4 15/16 2.438 39 XT 183.97 WEPS PDC Reamer 4 15/16 2.500 39 XT 189.65 3 HWDP(3 Jts.) 4 2.625 39 XT 280.65 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 310.62 2 HWDP(2 Jts.) 4 2.563 39 XT 371.62 180 Drill Pipe 4 3.340 39 XT 6,051.13 219 Drill Pipe 4 3.240 39 XT 13,007.79 42 HWDP 4 2.563 39 XT 14,291.39 174 Drill Pipe 4 3.240 39 XT 18,786.76 Drilling Parameters Flow Rate Cum Drill Time Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) End Depth(ftKB) Cum Depth(ft) (hr) Time(hr) (gpm) (10001bf) (rpm) SPP(psi) (10001bf) (10001bf) (1000Ibf) Off Btm Tq Dnll Tq 14,350.0 14,350.0 14,055.0 14,350.0 150 10 30 1,300.0 260 170 120 13.5 Wellbores Wellbore Name Wellbore API/UWI CD5-03 501032071800 :Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date ; End Date COND 42 35.9 115.0 3/9/2015 3/9/2015 SURFAC 13 1/2 115.0 2,409.0 10/18/2015 10/23/2015 INTRM1 11 2,409.0 14,350.0 10/23/2015 11/5/2015 PROD1 6 1/2 14,350.0 20,999.0 11/5/2015 11/13/2015 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Ken RIG SUPERVISOR SolstenXP 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom Page 2/3 Report Printed: 11/25/2015 • • Security Level: AK Development Jae Daily Drilling Report 14: 714.1f1 yy CD5-03 itlip Report Number: 17 ConocoP Rig: DOYON 19 Report Date: 11/3/2015 Head Count/Manhours Function Company Name Count Note SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 6 Ball Mill, 1 @ CD1 MUD ENGINEER MI Swaco 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 Rhino-Under-reamer Schlumberger SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment SERVICE ENGINEER Baker Hughes SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Halliburton Energy Services Inc. (HES) OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm WELLSITE GEOLOGIST Other Waters Petroleum CASING/TUBING Doyon Drilling Inc SERVICE ENGINEER Cameo SERVICE ENGINEER Schlumberger Page 3/3 Report Printed: 11/25/2015 COO CO OO D O N N N- N 00 Ln CDO c.0fl CA CO CO O N- LIDN M O O LO Cfl CO CO 00 M M N up d' V' N N M M CO M M M N N N N N N N N N N Y r C Q. 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Q C/ o N LL J CD 2 - - . ii E CA C i EC 110) C U) LCL L, N 0) I- V N N. ti co Z d' 0 u) II o N LL dM' Q Q _U _a _o Q t g L Q.J 0_J J .0 LCO OJ O E CA O O OHO 00 •a) Fj CO CO +i , 0 O N- O 0 0 1- r, (U i+ 000 -0 COCOco Ln v •i N co CO0O O Lu F- 0 vii Li_ c0 dr + M z rn O d .. .. 4-% r d v) "J' - m C C N C o y i 0 •t- a3 Q a3 Y M •y CAO O to.- W . > U U U C C6 Cll , U 1 O F- N I- - a n5 U C as d X L - ul W as E N_ D a_ 0) N N CC 0 a) _ = O C i- Cn a C C N ~ 15 N C6 Q ate+ I O O W O L •� w LL C � F- p C2 R a) O a ♦R♦ u) J o 0 0 0 0 0 0 0 0 Uj F- N ' U W v r�i M N N to O Z = fn w o n m _ a. m 3U IISS321d E 0 I 0 • • CD5-04 Surface Casing Well: CD5-04 10-3/4"45.5#L-80 BTC-M& Hyd 563 Surface Casing Date: 5/24/2015 Conoco Phillips Rig: Doyon 19 Alaska,Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 36.18 FMC 10-3/4" Casing Hanger .17 36.18 10-3/4", 45.5#, L-80, HYD563 Casing Pup, pin x pin 2.25 36.35 Jts 14 to 54 41 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 1746.26 38.60 XO 10-3/4", 45.5#, L-80, HYD563 Casing Box x 10-3/4" BTC-M Pin 9.72 1784.86 Jts 3 to 13 11 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 443.90 1794.58 10-3/4" Halliburton Float Collar 1.19 2238.48 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 85.02 2239.67 10-3/4" Ray Oil Tools Silver Bullet Float Shoe 2.34 2324.69 2327.03 2327.03 2327.03 2327.03 2327.03 10 3/4" Shoe at 2,327.03' MD/2231.44' TVD 2327.03 13 1/2" TD at 2,342' MD/2,244'TVD 2327.03 2327.03 2327.03 2327.03 2327.03 2327.03 2327.03 2327.03 1 Centek 10' up from shoe w/stop ring on Jt#1 2327.03 1 Centek 30' up from pin w/stop ring on Jt#2 2327.03 1 Centek 10' up from pin w/stop ring on Jt#3 2327.03 1 Centek every joint from #4 to#53 floating &XO 2327.03 No centralizer on last Jt 2327.03 54 Total Centek Centralizers 2327.03 2327.03 2327.03 2327.03 2327.03 2327.03 2327.03 Remarks: Use Run&Seal pipe dope on BTC-M, Seal Guard ECF on HYD 563 Up Wt 145 K Avg MU Tq with Volant- 11 k ft/lbs trq for BTC-M & 16 k ft/lbs trq for Hyd 563 Dn Wt 132 K Jts Bakerlocked to box end of#3 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:K.Harding/A.Dorr/T.Polasek .5 , a° • Cement Detail Report ArAe„ , CD5-04 OanaoaPhillips ream String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/24/2015 22:00 5/25/2015 01:30 CD5-04 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"Surface 36.2 2,327.0 No Yes Yes Casing Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 400.0 900.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.2 1,596.0 1,352 DeepCRETE 459.8 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 0.00 11.00 4.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,596.0 2,327.0 291 G 60.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report 1 CD5-04 Report Number: 7 Rig: DOYON 19 Report Date: 5/24/2015 Wet Type AFE Typ NetworWID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 3.91 7.0 0.00 2,342.0 2,342.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 7,685.57 142,146.19 425,627.37 1,794,613.56 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 36.00 -1.00 6/23/2015 Last Casing String SURFACE,2,327.0ftKB Ops and Depth @ Morning Report 24hr Forecast W.O.C.-R/D casing/cementing tools&equip. Cont.to pump cement as per dowel)&displace with rig. Flush stack &shut in annular.W.O.C. P/U&rack back 5"DP.Test BOPE Last 24hr Summary Cont.to run 10-3/4"to 2,329'. Not able to land on hanger. POOH 6 jts to 2,046'.Swap out jts. RIH w/casing f/2,046'&land on hanger @ 2,327'.Circ&cond mud for cement job.Pump cement as per Dowell. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills 37°F/WC 29°F Wind E 13 mph,VIS 10 mi, 55.0 Rig&Camp on high line power Clear Supervisor - Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB),::.:: End Depth(ftKB) Operation 00:00 10:30 10.50 SURFAC CASING PUTB P 125.0 2,300.0 Cont.to rum 10-3/4"casing f/125' to 2,300'.(Ran 13 jts BTC&41 Hyd 563 total, 1 Centrek centralizer per jt)Work through tight hole f/1,379'to 1,568'.Pump @2-4 bpm @110-130 psi. PU wt 110 k,hole in good condition on up stroke. 10:30 14:00 3.50 SURFAC CASING HOSO T Hole Undergau 2,300.0 2,329.0 M/U hanger&landing jt.Attempt Conditions ge/Tight to land on hanger&started taking Ho. wt @ 2,329'.Attempt to work past 2,329'with no success.Decision made to pull out of hole& reconfigure casing tally. 14:00 14:15 0.25 SURFAC CASING RURD T Hole Undergau 2,329.0 2,329.0 R/U power tongs&350 ton slips. Conditions ge/Tight Ho. 14:15 14:30 0.25 SURFAC CASING RURD T Hole Undergau 2,329.0 2,300.0 B/O of landing jt w/Volant tool& Conditions ge/Tight L/D same. Ho. 14:30 17:15 2.75 SURFAC CASING PULL T Hole Undergau 2,300.0 2,046.0 POOH&L/D 6 jts of casing Conditions ge/Tight f/2,300'to Ho. 17:15 18:15 1.00 SURFAC CASING PUTB T Hole Undergau 2,046.0 2,290.0 RIH w/6 new jts of casing f/2,046' Conditions ge/Tight to 2,290' Ho. 18:15 19:00 0.75 SURFAC CASING HOSO P 2,290.0 2,327.0 M/U hanger&landing jt. Break circ w/2.5 bpm @ 150 psi. RIH& land on hanger @ 2,327' 19:00 19:30 0.50 SURFAC CEMENT CIRC P 2,327.0 2,327.0 Stage flow rate to 8 bpm @ 340 psi.&circ B/U.Reciprocate pipe 20' Latest BOP Test Data Date I Com Page 1/3 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report • CD5-04 ( Report Number: 7 Rig: DOYON 19 Report Date: 5/24/2015 Time Log Time Start Depth Start Time End Time. Dur(hr) Phase Op Code ..Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 19:30 20:00 0.50 SURFAC CEMENT RURD P 2,327.0 2,327.0 R/U cement lines to Volant cement circ swivel. R/D 4'bail extensions &elevators. 20:00 21:45 1.75 SURFAC CEMENT CIRC P 2,327.0 2,327.0 Circ&cond mud for cement job w/8 bpm @ 340 psi. Reciprocate pipe 20'P/U wt 145,SO wt 132 21:45 00:00 2.25 SURFAC CEMENT CMNT P 2,327.0 2,327.0 PJSM on cementing. Rig pump 100.7 bbls nut plug spacer @ 8 bpm/530 psi.Dowell pump 1 bbl H2O&pressure test to 3000 psi (good).Dowell pump 72.7 bbls 10.5 ppg Mud Push @ 5 bpm/150 psi.Drop bottom plug. Dowell pumped 300 bbls 11.0 ppg DeepCRETE 1.91 ft3/sk yield lead cement @ 4-6 bpm/250-350 psi as of 24:00 hrs. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gap Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ib1/100ft') (Ibf/100ft2) (Ibf/100ft2) MBT(Ib/bbl) (mL/30min) pH (°F) (%) DRILPLEX 2,342.0 10.00 15.0 19.0 24.0 33.0 48.000 16.3 10.9 60.0 DRILPLEX 2,342.0 10.00 15.0 40.0 48.0 74.0 89.000 16.3 10.9 68.0 Injection Fluid Fluid. Source From Lease(bbl). Dest Vendor Manifest.Number Note Drilling Mud WBM 415.0 CD1-01 AES 7328,29 CD5-04 Sorce Well Welibores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des :=Size(in) Act Top(ftKB) Act Btm(f/KB) Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Casing Strings Csg Des s.Run Date r' OD(in) Wt/Len(lb/ft) Grade. Set Depth(ftKB) : Com SURFACE 5/24/2015 10 3/4 45.50 L-80 2,327.0 Shoe track Bakerlok to box end of jt#3 Ran 13 jts BTC&41 jts Hyd 563 Cement Surface Casing Cement -Started @ 5/24/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-04 SURFACE,2,327.OftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.2 2,327.0 3 400.0 Fluid ;;Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) ". i,Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Lead Cement DeepCRETE 1,352 459.8 11.00 1.91 36.2 1,596.0 Tail Cement G 291 60.6 15.80 1.17 1,596.0 2,327.0 Head Count/Manhours Function Company Name Count t Note RIG SUPERVISOR ConocoPhillips Company 1 Ken RIG SUPERVISOR Other RIG SUPERVISOR SolstenXP 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 29 Doyon Hands Page 2/3 Report Printed: 12/1/2015 Daily Drilling Report • Security Level: AK Development • CD5-04 Report Number: 7 Conoeoihillips Rig: DOYON 19 Report Date: 5/24/2015 Head Count/Manhours Function Company Name Count Note CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 Mud Engineers DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 4 2 MudrLoggers&2 Sample Catchers (HES) WELLSITE GEOLOGIST SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc WIRELINE Halliburton Energy Services Inc. (HES) SERVICE ENGINEER CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control LOGGING Gyrodata Inc. Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report • 2: CD5-04 imps . Report Number: 8 ConocoPh Rig: DOYON 19 Report Date: 5/25/2015 Wet Type ,. AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 4.91 8.0 0.00 2,342.0 2,342.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 2,985.93 145,132.12 172,246.65 1,966,860.21 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 36.00 -1.00 6/23/2015 Last Casing String SURFACE,2,327.0ftKB Ops and Depth @ Morning Report 24hr Forecast N/U BOPE Cont. N/D diverter system&N/U BOPE.Test BOPE's. Last 24hr Summary Cont.to pump cement as per Dowell. Displace w/rig&bump plug. CIP @ 1:22 hrs. De-energize knife valve on diverter line. Flush stack&function annular.Shut in well @ 2:00 hrs&monitor psi while W.O.C.Clean&clear floor of casing/cementing tools&equipment. P/U 5"DP&rack back. N/D diverter system. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 37°F/WC 32°F Wind N 7 mph,VIS 4 mi,Foggy 54.0 Rig&Camp on high line power Supervisor Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) ;'... Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (EKE) End Depth(ftKB) Operation 00:00 01:30 1.50 SURFAC CEMENT CMNT P 2,327.0 2,327.0 Dowell cont.to pump 159.8 bbls (459.8 bbls total) 11.0 ppg DeepCRETE 1.91 ft3/sk yield lead cement @ 4-6 bpm/250-400 psi. Dowell pump 60.6 bbls 15.8 ppg 1.17 ft3/sx Tail Design cement @ 4 bpm/100 psi. Drop top plug. Dowell pump 20 bbls H2O @ 5.5 bpm/90 psi.Rig displace w/194.9 bbls/1956 stks @ 95%of 10.0 ppg DrillPlex spud mud. Initial 10 bpm @ 840 psi&Final 3 bpm @ 400 psi. Increase to 500 psi over @ 900 psi&hold for 5 min.Check floats(good)&F/C(static). Reciprocated pipe 20'stroke with full returns 165 bbls good cement back to surface.CIP @ 1:22 hrs. 01:30 02:00 0.50 SURFAC CEMENT OWFF P 2,327.0 2,327.0 De-energize knife valve on diverter line.Flush stack with black water&function annular(3 times).Well shut in @ 2:00 hrs. 02:00 05:30 3.50 SURFAC CEMENT RURD P 0.0 0.0 R/D Volant CRT.Clean&clear floor of casing/cementing tools& equipment.R/U drilling bails&5" elevators&prep to P/U DP Annulus Pressure=13 psi 05:30 14:45 9.25 SURFAC CEMENT PULD P 0.0 0.0 LID 1 stand of SLB NMFC.P/U& rack back 76 stands of 5"DP Annulus Pressure=10 psi 14:45 15:15 0.50 SURFAC CEMENT SVRG P 0.0 0.0 Service rig&draw works. Latest BOP Test Data Date sl.. Corn Page 1/3 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report CD5-04 Ccxxs�814 Report Number: 8 A t�zks Rig: DOYON 19 Report Date: 5/25/2015 Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code :Activity Code-.. P-T-X Trbl Code - Trbl Class (EKB) End Depth(ftKB) Operation 15:15 18:45 3.50 SURFAC CEMENT PULD P 0.0 0.0 Cont.to P/U&rack back 23 stands of 5"DP Annulus Pressure=5 psi 18:45 19:45 1.00 SURFAC CEMENT MPDA P 0.0 0.0 M/U 2 stands of DP&install RCD element.Rack back in derrick. 19:45 20:00 0.25 SURFAC CEMENT RURD P 0.0 0.0 Clean&clear fllor.SIMOPS- install roller on skate 20:00 20:45 0.75 SURFAC CEMENT RURD P 0.0 Confirm 0 psi on under annular. Open annular&F/C(static).Drain stack&L/D landing jt. 20:45 00:00 3.25 SURFAC CEMENT NUND P R/D diverter system.Remove diverter line&knife valve.R/D riser&annular. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr,. Type Depth(ftKB) Dens(lb/gal) Via(s/qt) PV Calc(cP) (Ibf/100ft) (Ibf/100ft') (Ibf/100ft') (lbf/100fr) MBT(Ib/bbl) (mU3Omin) pH (°F) (%) DRILPLEX 2,327.0 10.00 18.0 7.0 3.0 10.0 11.000 16.3 9.5 66.0 DRILPLEX 2,327.0 10.00 16.0 10.0 3.0 10.0 11.000 16.3 9.5 67.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM 1195.0 CD1-01 AES 7331,32,33,34,35 CD5-04 Sorce Well Wel lbores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des Size(in) Act Top(EKE):" Act Btm(ftKB) Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Ken RIG SUPERVISOR Other RIG SUPERVISOR SolstenXP 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 1 RLG DRILL CREW Doyon Drilling Inc 29 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 Mud Engineers DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 2 2 Mud Loggers (HES) WELLSITE GEOLOGIST SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. Page 2/3 Report Printed: 12/1/2015 y • • Security Level: AK Development Daily Drilling Report CD5-04 Ph i lips Report Number: 8 Rig: DOYON 19 Report Date: 5/25/2015 Head Count/Manhours Function S' CompanyName Count Note CASING/TUBING Doyon Drilling Inc WIRELINE Halliburton Energy Services Inc. (HES) SERVICE ENGINEER Schlumberger 1 Rhino Reamer Hand CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control LOGGING Gyrodata Inc. Page 3/3 Report Printed: 12/1/2015 • • Security Level: AK Development 0 Daily Drilling Report ►fit CD5-04 o; �( Report Number: 9 conocbittRig: DOYON 19 Report Date: 5/26/2015 Well Type AFE Typ -'Network/ID# 'AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 5.91 9.0 0.00 2,342.0 2,342.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 5,826.68 150,958.80 256,196.68 2,223,056.89 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 36.00 -1.00 6/23/2015 Last Casing String SURFACE,2,327.0ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE. - Test BOPE.M/U MPD equipment&test.M/U 9-7/8"BHA. RIH&drill out Last 24hr Summary N/D diverter system. N/U BOPE. R/U flow box, modify Trip nipple length,fill stack with water,check for leaks,stack leaking at top flange of lower pipe ram, RD trip nipple,break BOP connections,inspect and change out API seal ring. NU flow box,flow line and trip nipple. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 42°F/WC 38°F Wind N9 mph,VIS 10 mi, 54.0 Rig&Camp on high line power Overcast Supervisor _ Title Ken Harding Rig Supervisor Dan Lowe Rig Supervisor Joseph Engel Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr). Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB)= Operation 00:00 04:00 4.00 SURFAC CEMENT NUND P 0.0 0.0 Cont.to ND riser,Annular and starting spool. Stage wellhead and Alpine speed head/double stud adapter in cellar. 04:00 05:30 1.50 SURFAC WHDBOP NUND P 0.0 0.0 NU wellhead 05:30 08:00 2.50 SURFAC WHDBOP NUND P 0.0 0.0 NU BOPS,RU Alpine speed head/DSA. 08:00 09:30 1.50 SURFAC WHDBOP NUND P 0.0 0.0 RU Choke and Kill lines on stack 09:30 11:00 1.50 SURFAC WHDBOP NUND P 0.0 0.0 RU double annular valves on wellhead,PU MOD trip nipple to rig floor. 11:00 11:30 0.50 SURFAC WHDBOP NUND P 0.0 0.0 Clear and clean rig floor,double check torque on DSA/speed head. 11:30 13:15 1.75 SURFAC WHDBOP MPDA P 0.0 0.0 RU MPD Flo-box and hoses. Install Trip nipple. 13:15 16:45 3.50 SURFAC WHDBOP MPDA P 0.0 0.0 Remove Trip nipple and modify to fit wellhead BOP stack configuration.Re-install trip nipple, RU Katch-Kan.Remove bales. 16:45 18:45 2.00 SURFAC WHDBOP MPDA P 0.0 0.0 Re-set Trip nipple. Fill BOP stack with water and check for leaks. Leak between Mud Cross and LPRs.Tighten flange bolts but still leaking. 18:45 22:15 3.50 SURFAC WHDBOP NUND T Well BOP's 0.0 0.0 Remove Trip nipple,Flow-box, Control flowline and break flange System connections between pipe rams inspect and change out API seal ring. 22:15 00:00 1.75 SURFAC WHDBOP NUND T Well BOP's 0.0 0.0 NU Flow box,flow line and Trip Control nipple. System Latest BOP Test Data Date I Com Page 1/2 Report Printed: 12/1/2015 • • Security Level: AK Development Daily Drilling Report ``�\\\ ' CD5-04 itlips Report Number: 9 Rig: DOYON 19 Report Date: 5/26/2015 Mud Check Data YP Cala Gel(10s) Gel(10m):.. Gel(30m) HTHP Filtrate .Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gal) Vis(slit) PV Calc(cP),. (Ibf/100ft') COM 00ft') (Ibf/100ft') '. (Ibf/1Dof) MBT(Ib/bbl) (mL/3omin) ' pH (°F) (%) DRILPLEX 2,327.0 10.00 19.0 9.0 5.0 8.0 10.000 16.3 9.7 59.0 DRILPLEX 2,327.0 10.00 17.0 6.0 4.0 8.0 10.000 16.3 9.5 59.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM 250.0 CD1-01 AES 7336 CD5-04 Sorce Well Wellbores Wellbore Name ,Wellbore API/UWI C05-04 501032071100 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) :Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Head Count/Manhours Function Company Name Count :-Note RIG SUPERVISOR ConocoPhillips Company 1 Ken RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Dan COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 0 RLG DRILL CREW Doyon Drilling Inc 29 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 Mud Engineers DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 2 2 Mud Loggers (HES) WELLSITE GEOLOGIST SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc WIRELINE Halliburton Energy Services Inc. (HES) SERVICE ENGINEER Schlumberger 1 Rhino Reamer Hand CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Kelly SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv 1 Lou-CD1 camp Comm Page 2/2 Report Printed: 12/1/2015 000 000 000 0 00000000 0 Ln .- CO I- r- N. r- Co Co CO CO Ln Ln U) "I' '}"1- 'n (C Ln Ln Cr 'Cr 'Cr Tr .71- 'Cr V Cr Cr 'C* Y y N C Q d 7 E c6_ a0+ H 7 7 mm u i f6 E A C) Ln 0 0 0 0 0 O O O O C) O O O 0 0 0 O C) C) O O1:3 X Cti W E a+ U) c O N Ln O LU O LU O Ln O LU O LI) O Ln O Ln O Ln O LL) C) > Cl) Ln Y .L O O O 7- ,- N N M CO Cr Ln Ln CO CON r� co CO C) O) co m E E to C1 r` C/) 3 +- N a- 0 - 000 0000 OO C: C — Lc') N CO N 0 - - - CD (.1) V N F- N ii'-' C7).� N co d' to CO CO CO N •C c)_ E dm O o.3 U) i N O T- N CO V Ln Co I- CO CP O 7- N CO NI- LI) (o N- CO O) O N 'LJ LS CO ) CO N- CO 4 O E N- - N N-- A- 1- Clc 11) N Y tL O Y � 0000 0000 000 U) LntnC U CO — O 0CDC) Ytl) `r= N to CC2 Ln Ln Ln Ln Ln LL) LC) Ln Ln Ln Ln Ln Ln � 'I' Cl) U— n E m •- NNNN NNNN NNN N NNN E L6m co 0 -5o" m— OO �, _c O � CV M NtL (0 N- CO C) 0 U3 RI V p y .0 0 LnO ; H m 0 o C) U ..+ .- OLnLUO OLn00 000 O 0000 N ' N MLAI- N NCoO) N aO � N O OCAO C- m 0 � ,- NO COCDON MU, 1*-- 0) N � LU CU 'a. 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Fp N. m W in CO00 X 11 F C) r- .J N �� LL p M 0 LL ON '� C � � O N O O " Y ~ w J o N , I M a) m � C .% r Rcn LL -' ri N @ U o 0 N I N O CO II NCA 1CD H 0_J QJ J .0 p) L i ea OJ in E 000 OOOC11 CU ti: m ',, , _O CAS 000 , C7 H r r,., LOn O O 'a N ~ U) v •i y N 0 0 3 C') w O 0 U O N CO E N I- O Lei) LL (I) I- I`- + 4+ z 0 Cl c - o CD a) -~ srn L0 a U O us N C g 0 0 ~ Ch I- C U 2 Co CO � a) � � L X a) E " N C O N W L y N N D O CL 0 L►- d Lt) O w d) C .- N d> `L- U .c -0 N CU 0 C 0 0 O ~ O O E Q Cl) U U) H y CO L o Cl) = 0. co N) J o o 0 0 0 0 0 Cr; E >, 'a; °3 U Y W o o o o Z0) ~ N U 11 CO N N �, m 32lflSSJ ld E E o = w 0 • • CD5-04 7-5/8"Intermediate Casing Well: CD5-04 ConocoPhillips 29.7#L-80 BTC-M & Hyd 563 Date: 6/10/2015 Alaska.Inc #4,0011 . Doyon 19 Depth Jt Number N fits°f Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.91 FMC 7.625" fluted hanger 2.64 34.91 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.33 37.55 Jts 238 to 282 45 Jts 7-5/8", 29.7#, L-80 H563 Casing Dopeless 1807.86 39.88 7-5/8", 29.7#, L80, H563 Box x BTC Pin XO 10.05 1847.74 Jts 146 to 237 92 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 3869.65 1857.79 7-5/8", HES-II Cementer(Stage Collar) (Qannik 5,173'-5,226') 3.02 5727.44 Jts 4 to 145 142 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 5973.49 5730.46 7-5/8", 29.7#, L-80, BTCM, Baffle Adapter Collar 1.51 11703.95 Jts 3 to 3 1 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 43.50 11705.46 7-5/8", 29.7#, L80, Weatherford Float Collar w/By-pass Adaptor 1.34 11748.96 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 84.26 11750.30 7-5/8", 29.7#, L80, Ray Oil Tools " Silver Bullet" Float Shoe 2.17 11834.56 Bottom of shoe >>> 11836.73 11836.73 11836.73 11836.73 11836.73 11836.73 TD 9-7/8" Hole at 11,853' MD/7,477 TVD (11' Hole @ 11,754') 11836.73 Casing Shoe 11,837' MD/7,474' TVD 11836.73 11836.73 1 Centek 10' up from shoe w/stop ring on Jt#1 11836.73 1 Centek 30' up from pin w/stop ring on Jt#2 11836.73 1 Centek on every joint, floating from #3 to#25 11836.73 1 Centek on every other joint, floating from #27 to#145 11836.73 1 Centek on every joint, floating from #147 to#168 11836.73 1 Centek on every joint, floating from #225 to#227 11836.73 1 Centek on every other joint, floating from #229 to#279 11836.73 1 Centek on joint#280 11836.73 138 Total Centrek Centralizers 11836.73 11836.73 237 joints of 7-5/8"29.7# BTC-M in the Pipe shed 6 more joints on sills outside 11836.73 46 joints of 7-5/8" 29.7# HYD563DPLS in the Pipe shed 3 more out side 11836.73 11836.73 Remarks: Shoe track Baker Locked to pin of jt#4 Up Wt N/A Run&Seal on the BTC-M, No thread compound on Dopeless Hyd 563 Dn Wt 125 K M/U Trq BTCM = 7 k ftlbs/trq Block Wt 60 K M/U Trq Hyd 563= 12.4 k ftlbs/trq Rig Supervisors:D. Lutrick, A. Dorr, T. Polasek Cement Detail Report CD5-04 Conn tulips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/10/2015 20:00 6/11/2015 02:15 CD5-04 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Isolate shoe to top of 10,425.0 11,836.7 Yes Yes Yes Cement HRZ Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 5 410.0 900.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,425.0 11,836.7 442 G 88.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 5.00 1,084.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Isolate Qannik 4,728.0 5,728.0 Yes Yes No Cement Q Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 5 290.0 1,190.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,727.0 5,727.0 442 G 91.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.00 534.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report CD5-04 Report Number: 24 APrzk�w Rig: DOYON 19 Report Date: 6/10/2015 Well Type AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 20.91 24.0 0.00 11,853.0 11,853.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 7,872.13 783,541.95 293,148.40 6,963,387.85 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 38.00 -3.00 6/25/2015 Last Casing String INTERMDIATE, 11,836.7ftKB Ops and Depth @ Morning Report 24hr Forecast Testing Pack Off to 5000 psi Cement 2nd stage. L/D landing jt.Set pack off. R/D casing tools& equip.L/D 5"DP Last 24hr Summary Cont.to run 7-5/8"casing&land on hanger @ 11,837'.Circ&cond mud for cement job.Cement 1st stage as per Dowell.Circ&cond mud for 2nd stage cement job.. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills 51°F/WC 47°F Wind NW 12 mph,VIS 10 mi, 54.0 Rig&Camp on high line power Cloudy Supervisor Title Donnie Lutrick Fld Drlg Supv Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB)` End Depth(ftKB) Operation 00:00 11:00 11.00 INTRM1 CASING PUTB P 8,940.0 11,779.0 RIH 7-5/8"29.7#L-80 BTCM& Hyd 563 f/8940'to 11,779'(Saw significantr excess drag once in HRZ f/10,447')SO wt 120 K 11:00 11:30 0.50 INTRM1 CASING HOSO P 11,779.0 11,837.0 M/U hanger&P/U landing jt& land casing on depth @ 11,836.73' 11:30 19:15 7.75 INTRM1 CEMENT CIRC P 11,837.0 11,837.0 Circ&cond.mud for cement job. Stage flow rate f/.3 bpm @ 540 psi to 8 bpm. ICP©675 psi&FCP @ 520 psi. 11.1+ppg in/out<21 YP 19:15 19:30 0.25 INTRM1 CEMENT SFTY P 11,837.0 11,837.0 PJSM-1st stage cement job 19:30 22:45 3.25 INTRM1 CEMENT CMNT P 11,837.0 11,837.0 Cement 1st stage cement as per Dowell.(Dowell pump 1.2 bbls H2O&psi test to 4000 psi(good), 40.1 bbls CW 100,40.1 bbls 12.0 ppg Mud Push II, Drop bypass plug,88.1 bbls 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement, 1.1 bbls H2O,Drop landing plug, 10.1 bbls H2O)Rig displace with 527.4 bbls 11.1 ppg LSND. ICP= 8 bpm @ 600 psi/FCP 3 bpm @ 410 psi. Pressure up to 900 psi& hold for 5 min.Check floats(good) Cemented with full returns.CIP @ 22:27 hrs.F/C(good) 22:45 00:00 1.25 INTRM1 CEMENT CIRC P 11,837.0 11,837.0 Pressure up to 3290 psi @ 64 stks &shear stage collar.Circ&cond mud w/8 bpm @ 530 psi. 11.1+ ppg in/out<21 YP Latest BOP Test Data ...Date I Com 6/2/2015 Test BOPE:With 5"test it test Annular to 250/2500 nsi&chart for 5 min Test[inner 3 5 x 6"VBRs to 250/3 500 nsi and hold for Page 1/3 Report Printed: 12/1/2015 . • Security Level: AK Development Daily • Drilling Report CD5-04 Report Number: 24 t:exsillii Rig: DOYON 19 Report Date: 6/10/2015 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr';.: Type Depth(ftKB) Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (Ib1/100fF) (Ibf/100ft') (Ibf/100ft') (Ibf/1:00W) ,MBT(Ib/bbl) (mL/30min) pH `(°F) (%) LSND 11,853.0 11.10 41 12.0 20.0 10.0 11.0 13.000 17.5 9.5 98.0 LSND 11,853.0 11.10 52 12.0 22.0 10.0 11.0 13.000 17.5 9.8 64.0 Injection Fluid Fluid s.Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-04 540.0 CD1-01 AES 7385,7386 CD5-04 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des ::Size(in) ;,Act Top(ftKB) Act Btm(ftKB) ;'.Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Casing Strings Csg Des Run Date OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Corn INTERMDIATE 6/10/2015 7 5/8 29.70 L80 11,836.7 Shoe track Bakerlok to pin end of jt#4 Ran 237 jts BTC&45 jts Hyd 563 Cement Intermediate Casing Cement -Started @ 6/10/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-04 INTERMDIATE, 11,836.7ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 10,425.0 11,836.7 3 410.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) Yield:.(IF/sack) Est Top(ftKB) - Est Elm(ftKB) Intermediate Cement G 442 88.1 15.80 1.16 10,425.0 11,836.7 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Casing Cement 4,728.0 5,728.0 3 290.0 Fluid Class Amount(sacks) Vol.Pumped(bbl) Dens(lb/gal) Yield(ftsack) Est Top(ftKB) :.,:,Est Elm(ftKB) Intermediate Cement G 442 91.4 15.80 1.16 4,727.0 5,727.0 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Donnie RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other RLG- DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 Mud Engineers DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 2 2 Mud Loggers (HES) WELLSITE GEOLOGIST SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc Page 213 Report Printed: 12/1/2015 • Daily Drilling Report Security Level: AK Development CD5-04 illi � <: Report Number: 24 Rig: DOYON 19 Report Date: 6/10/2015 Head Count/Manhours Function Company Name Count Note CEMENTING Halliburton Energy Services Inc. 1 Jack (HES) SERVICE ENGINEER Schlumberger CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Clayton SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm CASING/TUBING Page 3/3 Report Printed: 12/1/2015 • Security Level: AK Development -.., • Daily Drilling Report CD5-04 co'hiEhpS Report Number: 25 Rig: DOYON 19 Report Date: 6/11/2015 Well Type AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 21.91 25.0 0.00 11,853.0 11,853.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 4,455.03 787,996.98 168,934.11 7,132,321.96 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 39.00 -4.00 6/26/2015 Last Casing String INTERMDIATE, 11,836.7ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE Cont.Test BOPE.M/U 6-3/4"BHA.Single in hole w/4"DP.Drill out Last 24hr Summary Cont.to circ for 2 nd stage cement. Pump 2nd stage as per Dowell.R/D cementing hoses. LID landing jt. Retrieve WR. R/D casing tools&equip. L/D 5"DP. P/U 20 stands 4"DP.C/O rams&saver sub.R/U to test BOPE. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills 39°F/WC 35°F Wind N 5 mph,VIS 10 mi, 55.0 Rig&Camp on high line power Cloudy Supervisor Title Donnie Lutrick Fld Drlg Supv Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-7 X.. Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 00:15 0.25 INTRM1 CEMENT CIRC P 11,837.0 11,837.0 Circ&cond mud w/8 bpm @ 530 psi. 11.1+ppg in/out<21 YP 00:15 00:30 0.25 INTRM1 CEMENT SFTY P 11,837.0 11,837.0 PJSM-2nd stage cement job 00:30 02:45 2.25 INTRM1 CEMENT CMNT P 11,837.0 11,837.0 Cement 2nd stage cement as per Dowell.(Dowell pump 40.2 bbls CW 100,40.2 bbls 12.0 ppg Mud Push II,91.4 bbls 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement, 1.1 bbls H2O, Drop closing plug, 10.1 bbls H2O)Rig displace with 253 bbls 11.1 ppg LSND. ICP=8 bpm @ 340 psi/FCP 3 bpm @ 290 psi.Pressure up to 1190 psi& close stage collar.Cemented with full returns.CIP @ 2:10 hrs. F/C (good) 02:45 03:15 0.50 INTRM1 CEMENT RURD P 0.0 0.0 R/D cement lines&L/D landing jt 03:15 05:30 2.25 INTRM1 CEMENT WWSP P 0.0 0.0 Attempt to pull wear ring. Damaged wear ring&un-able to pull.Pull wear ring w/spring lock puller.Set pack off as per FMC& test to 5000 psi. 05:30 06:45 1.25 INTRM1 CEMENT PULD P 0.0 0.0 L/D 5"DP from derrick via mouse hole 06:45 07:15 0.50 INTRM1 CEMENT SVRG P 0.0 0.0 C/O hydraulic oil on top drive 07:15 15:15 8.00 INTRM1 CEMENT PULD P 0.0 0.0 L/D 5"DP from derrick via mouse hole.SIMOPS-Dowell perform LOT, flush annulus w/300 bbls H2O&freeze proptect w/82 bbls diesel) 15:15 16:15 1.00 INTRM1 CEMENT RURD P 0.0 0.0 R/D 5"elevators&R/U 4" elevators&single jt elevators. Install 90'mouse hole. 16:15 19:45 3.50 INTRM1 CEMENT PULD P 0.0 0.0 P/U&rack back 20 stands 4"DP via 90'mouse hole. Latest BOP Test Data Date I ' Corn 0/2/2015 Test ROPE With 5"test it test Annular to 250/2500 nsi&chart for 5 min Test unner 3 5 x 6"VRRs to 250/3 500 nsi and hold for Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development • Daily Drilling Report ...<� CD5-04 Cvnot)Phiiiips T' Report Number: 25 Rig: DOYON 19 Report Date: 6/11/2015 Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) '< ,.. End Depth(ftKB) Operation 19:45 20:15 0.50 INTRM1 CEMENT MPDA P 0.0 0.0 P/U 1 stand DP for MPD bearing& rack back. 20:15 22:15 2.00 INTRM1 CEMENT RURD P 0.0 0.0 C/O saver sub on top drive. (SIMOPS-C/O 7-5/8"casing rams to 3-1/2"X 6"VBR's) 22:15 22:45 0.50 INTRM1 CEMENT RURD P 0.0 0.0 CIO 90'mouse hole to 30'mouse hole for BHA 22:45 00:00 1.25 INTRM1 WHDBOP RURD P 0.0 0.0 Set test plug&fill choke manifold. R/U to test BOPE.R/U 4"test jt. Fill stack w/H20 Mud Check Data YP CaIc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp, Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') (Ibf/100fP) MBT(Ib/bbl) (mU30min) pH (°F) (%)'. LSND 11,853.0 11.10 51 7.0 28.0 10.0 13.0 14.000 17.5 9.5 61.0 LSND 11,853.0 11.10 50 15.0 21.0 11.0 14.0 14.000 17.5 9.5 64.0 Injection Fluid Fluid Source From Lease(bbl) r Dest Vendor Manifest Number Note Drilling Mud WBM CD5-04 840.0 CD1-01 AES 7387,88,89 CD5-04 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des Size(in) Act Top(EKE) Act Btm(ftKB) Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Head Count/Manhours Function:' Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Donnie RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other RLG- DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 Mud Engineers DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 2 2 Mud Loggers (HES) WELLSITE GEOLOGIST SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc CEMENTING Halliburton Energy Services Inc. 1 Jack (HES) SERVICE ENGINEER Schlumberger Page 2/3 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report • CD5-04 Ccsnocth iheps Report Number: 25 Rig: DOYON 19 Report Date: 6/11/2015 Head Count/Manhours Function+ Company Name Count Note CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Clayton SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv 1 Johnnie Hill @ CD1 Comm CASING/TUBING Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development — Daily Drilling Report • f CD5-04 �jtlps Report Number: 26 Icx:moRig: DOYON 19 Report Date: 6/12/2015 Well Type - AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 22.91 26.0 0.00 11,853.0 11,853.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 47,105.80 835,102.78 215,011.00 7,347,332.96 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 40.00 -5.00 6/27/2015 Last Casing String INTERMDIATE, 11,836.7ftKB Ops and Depth @ Morning Report 24hr Forecast RIH P/U 4"DP—7,000' Cont.to drill out stage collar. RIH to baffle collar.Test casing.Slip& cut drill line. Drill out.Displace to FloPro.FIT. Drill ahead 6-3/4" production section. Last 24hr Summary R/U to test BOPE.Test BOPE. M/U 6-3/4"BHA.Single in hole w/4"DP to 5,606'Test casing to 1000 psi.Wash f/5,606'to TOC @ 5,725'Drill out stage collar to 5,726' General Remarks Weather Head Count No Incidents, No Accidents,&No Spills 54°F/WC 51°F Wind W 10 mph,VIS 10 mi, 58.0 Rig&Camp on high line power Cloudy Supervisor Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 01:45 1.75 INTRM1 WHDBOP RURD P 0.0 0.0 PSI test BOPE&check for leaks. (SIMOPS-change mud bucket rubbers to 4", L/D 5"subs&XO's, install skate roller) 01:45 09:00 7.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Test BOPE w/3 1/2",4"&4-1/2" test jts.(Annular&HCR choke/kill 250/2500 psi&chart for 5 min- passed)(Choke valves#1 -14, HCR choke/kill,man choke/kill, needle valve,dart valve,FOSV, upper/lower 3 1/2"x 6"VBR's, blind rams to 250/3500 psi for 5 min-passed)Draw down test on man/super choke to 1100 psi. Accumulator test, Int 3075 psi/ 1450 psi after function,29 sec to first 200 psi&209 sec to full system psi.4 bottles @ 2000 psi. Gas alarms tested.Test witnessed by AOGCC Johnnie Hill 09:00 10:30 1.50 INTRM1 WHDBOP RURD P 0.0 0.0 Blow down lines. Pull test plug& install wear ring. 10:30 10:45 0.25 INTRM1 CEMENT RURD P 0.0 0.0 C/O elevatos&prep rig floor. 10:45 13:45 3.00 INTRM1 CEMENT BHAH P 0.0 371.0 PJSM-M/U 6-3/4"BHA#4 as per SLB to 371' 13:45 15:00 1.25 INTRM1 CEMENT PULD P 371.0 1,504.0 RIH f/371'to 1,504'while picking up 4"DP from pipe shed. 15:00 15:45 0.75 INTRM1 CEMENT DHEQ P 1,504.0 1,504.0 Shallow hole test MWD w/220 gpm @ 1080 psi,60 rpm @ 1 k trq (good) 15:45 20:45 5.00 INTRM1 CEMENT PULD P 1,504.0 5,606.0 RIH f/1,504'to 5,606'while picking up 4"DP from pipe shed. Latest BOP Test Data Date Com 6/12/2015 Test ROPF w/3 1/2" 4"&4-1/2"test its (Annular&HCR choke/kill 250/2500 nsi&chart for 5 min-passed) (Choke valves#1 -14 Page 1/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report > ,�� ... CD5-04 Phitl ps Report Number: 26 Rig: DOYON 19 Report Date: 6/12/2015 Time Log Time Start Depth Start Time End Time iDur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth.(ftKB) Operation 20:45 21:30 0.75 INTRM1 CEMENT PRTS P 5,606.0 5,606.0 R/U testing equip. Pressure test casing to 1000 psi for 10 min (good). RID testing equip. 21:30 22:15 0.75 INTRM1 CEMENT COCF P 5,606.0 5,725.0 Wash in hole with stands from derrick f/5,606'to 5,725'.Tag TOC @ 5,725'. 22:15 00:00 1.75 INTRM1 CEMENT DRLG P 5,725.0 5,726.0 Drill out cement&stage collar f/5,725'to 5,726'w/175 to 220 gpm @ 1100-1390 psi,40-80 rpm @4-6ktrq, 10-15WOB PU wt 126 k,SO wt 106 k,ROT wt 118 k Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth.(ftKB) Dens(Ib/gal) Vis(s/qt) PVCalc(cP) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft').`- (Ibf/100ft') MBT(Ib/bbl) (mL/3Omin) pH (°F) (%) LSND 11,853.0 11.10 54 7.0 28.0 10.0 12.0 13.000 17.5 9.6 54.0 LSND 11,853.0 11.10 52 12.0 24.0 10.0 12.0 13.000 17.5 9.4 58.0 Drill Strings: BHA No.4 Production / Bit Run No, <Bit Run?>- 6 3/4in,MM55,12611109 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 11,853.0 18,878.0 0.38 10/10/10/10/10 1-1-BT-T-X-I-ER-TD Drill String Components Jts Item Des OD(in) ID(in) ; Top,Conn Sz(in) Top Thread Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 61.08 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 89.90 3 HWDP(3 Jts.) 4 2.563 39 XT 181.86 WEPS PDC Reamer 4.92 2.563 39 XT 187.57 XO-XT39 Box x 3.5lF Pin 5.05 2.250 39 XT 190.58 Steel Float Sub w/NPFV 4 3/4 2.250 3 1/2 IF 192.81 Steel Float Sub w/NPFV 5 2.250 3 1/2 IF 195.25 1 Non Mag Flex Collar 4 5/8 2.440 3 1/2 IF 224.37 1 Non Mag Flex Collar 4.88 2.250 3 1/2 IF 254.30 NM Stabilizer 4.78 2.250 3 1/2 IF 260.64 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 291.51 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 324.64 Periscope-LWD(Dir&Logging) 4 3/4 2.250 35 NC 349.65 PowerDrive X6 4.88 3.000 35 NC 371.46 Drilling Parameters Flow Rate Cum.Dull Time Sliding ,.(gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) End Depth(ftKB) Cum Depth(ft) ''(hr) Time(hr)1 (9pm) (1000Ibf) I (rpm) "' SPP(psi) (10001b1) (1000Ibf) (100016f) Off Btm Tq (Drill Tq 11,853.0 11,853.0 5,725.0 5,725.0 220 15 60 1,390.0 126 118 106 4.5 4.0 Welibores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date... CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Head Count/Manhours _ Function Company -Name Count ''Note RIG SUPERVISOR ConocoPhillips Company 1 Rick Page 2/3 Report Printed: 12/1/2015] Security Level: AK Development • Daily Drilling Report CD5-04 Report Number: 26 Rig: DOYON 19 Report Date: 6/12/2015 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 1 RLG-Jordan DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 4 2 Mud Loggers/2 Sample Catches @ CD1 (HES) WELLSITE GEOLOGIST 2 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc CEMENTING Halliburton Energy Services Inc. (HES) SERVICE ENGINEER Schlumberger CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Clayton SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm CASING/TUBING Page 3/3 Report Printed: 12/1/2015 ' g\ Security Level: AK Development �,��. Daily Drilling Report 0+o ;, , i , -.,, CD5-04 Conde hill Report Number: 27 Ricks Rig: DOYON 19 Report Date: 6/13/2015 Well Type AFE Typ Network/ID# ' AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 23.91 27.0 0.00 11,853.0 11,853.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 11,555.05 846,657.83 191,831.29 7,539,164.25 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 41.00 -6.00 6/28/2015 Last Casing String INTERMDIATE, 11,836.7ftKB Ops and Depth @ Morning Report 24hr Forecast Drilling Ahead—12,000' FIT to 12.8 ppg. Install MPD element.Drill ahead 6-3/4"production section. Last 24hr Summary Cont.to drill out stage collar to 5,727'.W&R to 5,891'. Rack back 3 stands in derrick.Cont.to RIH to 11,538'while P/U 4"DP.Test casing.Slip&cut drill line. Drill out to 11,873'.Displace to FloPro. Pull inside casing. F/C General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 56°F,Wind NE 6 mph,VIS 10 mi,Cloudy 58.0 Rig&Camp on high line power Supervisor - Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 01:30 1.50 INTRM1 CEMENT DRLG P 5,726.0 5,727.0 Drill out cement&stage collar f/5,726'to 5,727'w/175 to 220 gpm @ 1100-1390 psi,40-80 rpm @4-6ktrq, 10-15 WOB PU wt 126 k,SO wt 106 k,ROT wt 118 k 01:30 02:45 1.25 INTRM1 CEMENT REAM P 5,727.0 5,891.0 W&R f/5,727'to 5,891'w/220 gpm @ 1400 psi,60 rpm @ 4 k trq. Work thru stage collar 2 times (free) 02:45 03:00 0.25 INTRM1 CEMENT TRIP P - 5,891.0 5,601.0 POOH f/5,891'to 5,601'(racked back 3 stands) 03:00 12:00 9.00 INTRM1 CEMENT PULD P 5,601.0 11,348.0 RIH while picking up 4"DP f/5,601'to 11,348'.W&R thru periodic stringers 8,640', 10,388', &10,950'w/200 gpm @ 1700 psi, 40 rpm @ 7-11 ktrq. 12:00 13:30 1.50 INTRMI CEMENT RURD P 11,348.0 11,348.0 L/D short mouse hole&M/U 90' mouse hole. Remove skate roller. 13:30 14:00 0.50 INTRM1 CEMENT PULD P 11,348.0 11,538.0 M/U 2 stands&rack back via 90' mouse hole. 14:00 16:00 2.00 INTRM1 CEMENT PRTS P 11,538.0 11,538.0 R/U testing equip.&test casing to 3500 psi&chart for 5 min.R/D testing equip. 16:00 17:00 1.00 INTRMI CEMENT 'SLPC P 11,538.0 11,538.0 Slip&cut 60'drill line 17:00 17:30 0.50 INTRM1 CEMENT SVRG P 11,538.0 11,538.0 Service rig,draw works&top drive. 17:30 18:00 0.50 INTRM1 CEMENT RURD P 11,538.0 11,538.0 Calibrate block height&wt indicator. M/U stand in mouse hole. Latest BOP Test Data Date I Com 6/12/2015 Te.t •0• /3 1/ " 4"&4- /2"fes it. ,it r ' HCR chnke/kill 250/2500 nsi& chart for 5 min-nassedl (Choke valves#1 - 14 Page 1/3 Report Printed: 12/1/2015 Daily Drilling Report • Security Level: AK Development .. ,. CD5-04 ii(irReport Number: 27 con000fttts Rig: DOYON 19 Report Date: 6/13/2015 Time Log Time Start Depth Start Time End Time ,.Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 18:00 19:30 1.50 INTRM1 CEMENT COCF P 11,538.0 11,698.0 PJSM.SPR's.W&R f/11,538'to 11,698'w/220 gpm @ 1970 psi, 60 rpm @ 13 k trq.TOC @ 11,698' 19:30 21:45 2.25 INTRM1 CEMENT DRLG P 11,698.0 11,853.0 Drill cement,baffle collar,float collar,shoe track&rat hole f/11,698'to 11,853'w/220 gpm @ 1970 psi,60 rpm @ 13 k trq. 21:45 22:00 0.25 INTRM1 CEMENT DDRL P 11,853.0 11,873.0 Drill 20'new formation f/11,853'to 11,873'MD/7,480'TVD w/250 gpm @ 2750 psi,60 rpm @ 14.5 k trq.ADT 0.37 hrs PU wt 200 k,SO wt 130 k, ROT wt 150 k 22:00 23:30 1.50 INTRM1 CEMENT DISP P 11,873.0 11,824.0 Pump 30 bbls spacer&displace hole to new 10.2 ppf FloPro w/250 gpm©2750-2190 psi,60 rpm @ 12-9 k trq. Pull inside 7-5/8" casing shoe @ 11,824' 23:30 00:00 0.50 INTRM1 CEMENT OWFF P 11,824.0 11,824.0 SPR's. F/C-slight ooze then static. Mud Check Data YP Calc. Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate:: Density Temp. Solids,Corr. Type 'Depth(ftKB) Dens(lb/gal) Vie(s/qt) PV Calc(cP) (Ibf/100f2) (Ibf/100fF) (Ibf/100ft2) (Ibf/100ft') MBT(lb/bbl) (mL/3Omin) pH (CF) (%) LSND 11,853.0 11.10 54 16.0 27.0 12.0 23.0 27.000 17.5 10.8 82.0 LSND 11,853.0 11.10 46 11.0 23.0 11.0 12.0 14.000 17.5 10.9 71.0 Injection Fluid Fluid Source :.From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-04 280.0 CD1-01 AES 7390 CD5-04 Source Well Drill Strings: BHA No.4 - Production / Bit Run No. <Bit Run?>-k6 3/4in,MM55,12611109 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 11,853.0 18,878.0 0.38 10/10/10/10/10 1-1-BT-T-X-I-ER-TD Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 61.08 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 89.90 3 HWDP(3 Jts.) 4 2.563 39 XT 181.86 WEPS PDC Reamer 4.92 2.563 39 XT 187.57 XO-XT39 Box x 3.51F Pin 5.05 2.250 39 XT 190.58 Steel Float Sub w/NPFV 4 3/4 2.250 3 1/2 IF 192.81 Steel Float Sub w/NPFV 5 2.250 3 1/2 IF 195.25 1 Non Mag Flex Collar 4 5/8 2.440 3 1/2 IF 224.37 1 Non Mag Flex Collar 4.88 2.250 3 1/2 IF 254.30 NM Stabilizer 4.78 2.250 3 1/2 IF 260.64 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 291.51 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 324.64 Periscope-LWD(Dir&Logging) 4 3/4 2.250 35 NC 349.65 PowerDrive X6 4.88 3.000 35 NC 371.46 Drilling Parameters Flow Rate Cum Drill Time Sliding I (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) End Depth(ftKB) Cum Depth(ft):.` (hr) Time(hr). (gpm) (1000Ibf) (rpm) SPP(psi) (1000Ibf) (1000Ibf) (1000Ibf) Off Btm Tq `Drill Tq 11,698.0 11,853.0 220 15 60 1,970.0 215 155 117 13.0 11.0 11,853.0 11,873.0 20.00 0.37 250 15 60 2,900.0 200 150 130 14.5 12.0 Page 2/3 Report Printed: 12/1/2015 • Security Level: AK Development • Daily Drilling Report �" CD5-04 • c t iiiips Report Number: 27 COM3Rig: DOYON 19 Report Date: 6/13/2015 Wellbores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des "Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date.'. CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 1 RLG-Jordan DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks, housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 4 2 Mud Loggers/2 Sample Catches @ CD1 (HES) WELLSITE GEOLOGIST 2 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc CEMENTING Halliburton Energy Services Inc. (HES) SERVICE ENGINEER Schlumberger CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Clayton SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm CASING/TUBING Page 3/3 Report Printed: 12/112015 Security Level: AK Development •A4--:';c:- -, ik,4.; III 0 r Daily Drilling Report .44%0 N. '- CD5-04 iii Report Number: 28 Rig: DOYON 19 Report Date: 6/14/2015 Well Type i AFE Typ Network/ID# AFE+Supp Amt(Cost) Development ORIGINAL 10379146 12,220,920.00 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-04 ALPINE 24.91 28.0 1,609.00 11,873.0 13,482.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) 34,690.55 881,348.38 321,009.35 7,860,173.60 Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/18/2015 5/21/2015 35.00 40.74 -5.74 6/27/2015 Last Casing String INTERMDIATE, 11,836.7ftKB Ops and Depth @ Morning Report 24hr Forecast Drilling Ahead—13,950' Drill 6-3/4"Production Section to 18,792' Last 24hr Summary FIT to 12.8 ppg. Install MPD element. Drill ahead 6-3/4"production section f/11,873'to 13,482' General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 64°F,Wind NE 10 mph,VIS 9 mi,Cloudy 58.0 Rig&Camp on high line power Supervisor Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Weifeng Dai Drilling Engineer Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code : Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 01:00 1.00 INTRM1 CEMENT FIT P 11,824.0 11,824.0 R/U&FIT ti 12.8ppg @ 1010 psi. R/D testing equipment. 01:00 03:30 2.50 PROD1 DRILL MPDA P 11,824.0 11,824.0 Remove trip nipple.M/U soare MPD element bearing&rack back in derrick. Install MPD element bearing&line up chokes&system to drill with MPD. 03:30 04:00 0.50 PROD1 DRILL REAM P 11,824.0 11,873.0 W&R f/11,824'to 11,873'w/215 gpm @ 1700 psi,60 rpm @9k trq. 04:00 12:00 8.00 PROD1 DRILL DDRL P 11,873.0 12,395.0 Drill ahead f/11,873'to 12,395' MD/7,479'TVD,ADT 5.81 hrs, ECD 11.48 ppg,250 gpm,2300 psi,WOB 15, 150 rpm, PU wt 198 k,SO wt 123 k,ROT wt 154 k, Drill Trq 13,Off Btm Trq 11,2000 units average drill gas 12:00 00:00 12.00 PROD1 DRILL DDRL P 12,395.0 13,482.0 Drill ahead f/12,395'to 13,482' MD/7,395'TVD,ADT$.97 hrs, ECD 11.85 ppg,250 gpm,2580 psi,WOB 10-15, 150 rpm, PU wt 194 k,SO wt 124 k,ROT wt 154 k, Drill Trq 12,Off Btm Trq 8,7000 units average drill gas Mud Check Data YP Calc: Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr Type Depth(ftKB) Dens.(Ib/gal) Vis(s/qt) PV Calc(cP) .(Ibf/1001V) (Ibf/100fF) (Ibf/100fF) (Ibf/100fF) MBT(Ib/bbl) (mLJ30min) pH (CF) (%) Flo Pro NT 13,252.0 10.20 52 17.0 24.0 15.0 17.0 18.000 2.5 2.0 9.5 98.0 Flo Pro NT 12,697.0 10.20 52 14.0 25.0 13.0 15.0 17.000 1.3 9.3 89.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-04 560.0 CD1-01 AES 7391,92 CD5-04 Source Well Drill Strings: BHA No.4 - Production / Bit Run No. <Bit Run?> 6 3/4in,MM55,12611109 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 11,853.0 18,878.0 0.38 10/10/10/10/10 1-1-BT-T-X-I-ER-TD _Latest BOP Test Data Date Corn 6/12/2015 Test ROPE w/3 1/2" 4"&4-1/2"test its (Annular& HCR choke/kill 250/2500 nsi&chart for 5 min-nassedl(Choke valves#1 - 14 Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report • 'Z '� CD5-04 ilimp Report Number: 28 cxxicooPhRig: DOYON 19 Report Date: 6/14/2015 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread I Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 61.08 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 89.90 3 HWDP(3 Jts.) 4 2.563 39 XT 181.86 WEPS PDC Reamer 4.92 2.563 39 XT 187.57 XO-XT39 Box x 3.51F Pin 5.05 2.250 39 XT 190.58 Steel Float Sub w/NPFV 4 3/4 2.250 3 1/2 IF 192.81 Steel Float Sub w/NPFV 5 2.250 3 1/2 IF 195.25 1 Non Mag Flex Collar 4 5/8 2.440 3 1/2 IF 224.37 1 Non Mag Flex Collar 4.88 2.250 3 1/2 IF 254.30 NM Stabilizer 4.78 2.250 3 1/2 IF 260.64 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 291.51 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 324.64 Periscope-LWD(Dir&Logging) 4 3/4 2.250 35 NC 349.65 PowerDrive X6 4.88 3.000 35 NC 371.46 Drilling Parameters Flow Rate Cum.Dnll Time. Sliding. (gpm) WOB RPM PU Str:Wt Drill Str Wt SO Str Wt Start(ftKB) End Depth(ftKB) Cum Depth(ft) (hr) Time(hr) >(gpm) (1000lbf) (rpm) SPP(psi) (100016f) (10001bf) (10001v) Off Btm Tq DnlI Tq 11,853.0 11,873.0 20.00 0.37 250 15 60 2,900.0 200 150 130 14.5 12.0 11,873.0 12,395.0 542.00 6.18 250 15 150 2,300.0 198 154 123 13.0 11.0 12,395.0 13,482.0 1,629.00 15.15 250 15 150 2,580.0 194 154 124 12.0 8.0 Wellbores Wellbore Name Wellbore API/UWI CD5-04 501032071100 Section Des': Size(in) Act Top(ftKB) Act Btm(ftKB)I Start Date End Date CONDI 20 36.0 115.0 3/9/2015 3/9/2015 SURFAC 131/2 115.0 2,342.0 5/21/2015 5/28/2015 INTRM1 9 7/8 2,342.0 11,853.0 5/28/2015 6/14/2015 PROD1 61/2 11,853.0 18,878.0 6/14/2015 6/24/2015 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft):' 11,954.95 85.95 338.44 7,486.82 5,252.80 3,545.49 6,031.58 4.04 12,003.28 87.53 337.43 7,489.57 5,289.61 3,590.20 6,013.46 3.88 12,050.62 88.99 333.77 7,491.01 5,324.43 3,633.29 5,993.92 8.32 12,096.95 90.39 336.08 7,491.26 5,358.15 3,675.24 5,974.28 5.83 12,144.16 91.65 332.36 7,490.42 5,392.10 3,717.74 5,953.76 8.32 12,240.09 92.69 332.64 7,486.78 5,459.04 3,802.77 5,909.50 1.12 12,335.17 92.85 331.13 7,482.19 5,524.62 3,886.53 5,864.74 1.60 12,430.91 93.07 328.79 7,477.25 5,588.28 3,969.29 5,816.89 2.45 12,526.15 91.39 329.27 7,473.54 5,650.49 4,050.89 5,767.91 1.83 12,620.64 90.82 328.46 7,471.72 5,712.04 4,131.75 5,719.07 1.05 12,716.50 90.27 328.39 7,470.81 5,773.93 4,213.42 5,668.87 0.58 12,811.65 90.44 327.84 7,470.22 5,834.96 4,294.21 5,618.62 0.61 12,907.35 90.31 328.78 7,469.59 5,896.61 4,375.64 5,568.35 0.99 13,002.43 90.34 329.29 7,469.05 5,958.76 4,457.16 5,519.43 0.54 13,097.18 90.38 329.20 7,468.46 6,020.97 4,538.59 5,470.98 0.10 13,192.36 90.34 330.04 7,467.86 6,083.92 4,620.69 5,422.84 0.88 13,287.66 90.31 329.15 7,467.32 6,146.93 4,702.89 5,374.61 0.93 13,383.20 90.27 328.83 7,466.83 6,209.33 4,784.77 5,325.39 0.34 13,478.67 90.45 328.75 7,466.23 6,271.43 4,866.43 5,275.92 0.21 Page 2/3 Report Printed: 12/1/2015 •0 • Security Level: AK Development kke Daily Drilling Report CD5-04 Report Number: 28 conn hillipcs Rig: DOYON 19 Report Date: 6/14/2015 Leak Off and Formation Integrity Tests Leak '-:Dens Fluid LO Eq Fluid Den off? Last Casing String Run Depth(ftKB) (Ib/gal) Fluid P Surf Applied(psi) z(Ib/gal) P LeakOff(psi) No INTERMDIATE, 11,836.7ftKB 11,837.0 10.20 WBM 1,020.0 12.83 4,980.1 Head Count/Manhours Function Company Name Count Note RIG SUPERVISOR ConocoPhillips Company 1 Rick RIG SUPERVISOR Other RIG SUPERVISOR Other 1 Adam COMPANY ENGINEER ConocoPhillips Company 1 Rig Engineer-Tom SAFETY Other 1 RLG-Jordan DRILL CREW Doyon Drilling Inc 30 Doyon Hands CATERING/CAMP 5 Cooks,housekeeping GIS MI Swaco 4 Ball Mill SERVICE ENGINEER-MPD MI Swaco MUD ENGINEER 2 DIRECTIONAL Schlumberger 2 MWD Schlumberger 2 MUD LOGGING Halliburton Energy Services Inc. 4 2 Mud Loggers/2 Sample Catches @ CD1 (HES) WELLSITE GEOLOGIST 2 SERVICE ENGINEER FMC Corporation Wellhead 1 1 @ CD1 Equipment CASING/TUBING PESI-Petroleum Equipment& Services SERVICE ENGINEER Gyrodata Inc. CASING/TUBING Doyon Drilling Inc CEMENTING Halliburton Energy Services Inc. (HES) SERVICE ENGINEER Schlumberger CEMENTING Halliburton Energy Services Inc. (HES) REGULATORY Alaska Clean Seas SERVICE ENGINEER-MPD SolstenXP 1 Clayton SERVICE ENGINEER Quadco/Totco OTHER Other 1 Beacon Site Control REGULATORY AOGCC-Alaska Oil&Gas Consv Comm CASING/TUBING Page 3/3 Report Printed: 12/1/2015 r- r- .cr •- C) Ln r- co -, r) r- u U) L. CO CO 00 M CO CO r- r- r- r-: r- r- r- co r` Y 'W CO M CO CO CO CO CO CO CO CO M M M M CO VJ 4- O c- CD C..) � - O L-) 0 0 O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 X CD - a. U) c O N U0 O Lf) O LC) O U3 O U1 O Ln O LU O LO O U3 O LC) O > �i SZ — •L 000 •- CV NM CO - Lf) L° (O COI� r- 00006) 6) 0 m E Po ami U) a c MOcoco Nccr- CO - CON O CflM O • 6) H 1.0 V st N00LCA CO r- N CO NOO N 0 L O.u) r- N M ct 'ct Ln CO CO CO CO LO LU '1- a) •p. fn O Q. 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O m O O 'IL :-1 LLh \\ H QCK = 2 L H — QJ 0_J J a) L R 9 Lo E (0. 0: O O O d' I N m 0 .-- N OOOCD M C) 0 }' O O O -a M H Lt7 H •: y MOO 3 CO H U Ln Li- d -:-C _ + N z 4.4 c 0 C C a) 2 � ' CA 2 0 c4 C(0 c, 0 'y 0)U' D 0).� d 3 > t iczl C6 c c ui O I- to 1 L N M N -o d rn � go ftCV W N I__ 1D_— Cn in L d O 0 a) ,_,(15 4-'„, o0 O LL H O c E Q a) 0 U) �' H �+ co , I 0 CV c a ea j5 U) ) 0 0 0 0 0 0 0 0 0 ui E U1 F- N Y C.1 Y W o c' o ,L.- 0 '0n C U I I 7 M co N N m ?� 32if1SS321d E m = E 0 I w 0 CD5-05 Surface Casing Well: CD5-05 10-3/4"45.5#L 8O BTC-M& Hyd 563 Syrface Casing Date: 8/15/2015 ConocoPhillips Rig: Doyon 19 Alaska,Inc. 0 a I Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 • RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 35.10 10-3/4", 45.5#, L-80, HYD563 Casing (Cutoff Joint) 37.50 35.10 Jts 20 to 52 33 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 1411.16 72.60 XO 10-3/4", 45.5#, L-80, HYD563 Casing Box x 10-3/4" BTC-M Pin 9.81 1483.76 Jts 3 to 19 17 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 686.67 1493.57 10-3/4" Ray Oil Tools Float Collar 2.10 2180.24 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 82.22 2182.34 10-3/4" Ray Oil Tools Silver Bullet Float Shoe 2.35 2264.56 2266.91 2266.91 2266.91 2266.91 2266.91 10 3/4" Shoe at 2267' MD/2150.5' TVD 2266.91 13 1/2" TD at 2285' MD/2164.8' TVD 18' rathole 2266.91 2266.91 2266.91 2266.91 2266.91 2266.91 1 Centek 10' up from shoe w/stop ring above on Jt#1 2266.91 1 Centek 30' up from pin w/stop ring above and below on Jt#2 2266.91 1 Centek 20' up from pin w/stop ring above on Jt#3 2266.91 1 Centek every joint from #4 to#52 floating 2266.91 52 Total Centek Centralizers 2266.91 2266.91 2266.91 2266.91 2266.91 2266.91 56 joints in shed: Run 53 jnts., 3 jts. stay out 2266.91 2266.91 Note: Pipe stuck 8' high 2266.91 Cutoff length of joint# 53 to LR = 5.77' 2266.91 Emergency slips and Transition nipple installed 2266.91 Remarks: Use Run &Seal pipe dope on BTC-M, Seal Guard ECF on HYD 563 Up Wt 195 K Avg MU Tq- 11 k ft/lbs trq for BTC-M& 16 k ft/lbs trq for Hyd 563 Dn Wt 107 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Rig Supervisors:Dave Burley,Dan Lowe, Tom Polasek 11111 Cement Detail Report to CD5-05 ConooNPhililps 'N R7.xk� String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/15/2015 15:23 8/16/2015 01:02 CD5-05 Comment Pump 100.1 bbl of 10.5 ppg MudPush II at 4.8-5.2 BPM, 120-210 psi. Unsting from Volant tool, insert bottom cement plug,sting in with Volant tool. Pump 471.1 bbl of 11.0 LiteCRETE Lead cement plus additives at 5.7 to 7.1 BPM,290-330 psi. Reciprocate pipe 6-8'throughout. Note: Had cement returns to surface after 450 bbl of Lead was pumped. Cement returns to surface after displacement was 275 bbl. Pump 60.1 bbl of 15.8 ppg"G"Tail cement at 2.7 bbl,while reciprocating pipe(PU= 195K,SO= 107K).Slowed pump rate due to pump jacking and cement line whipping in derrick. Casing string stuck 8'high while reciprocating,after 44 bbl of Tail cmt pumped.Continue pumping remaining cmt with returns to surface. (00:10 hrs). Shut down cement pump,un-sting Volant tool from casing and insert top cement plug.Sting in with Volant tool and pump 20.1 bbl of water with cement pump and shut down. Displace with rig pump at 3-6 BPM,430-680 psi. Had partial returns during first 40 bbl pumped increasing to full returns.Slowed pumps to 3 BPM,430-450 psi for last 40 bbl of displacement. Bumped plug as calculated at 189.8 bbl pumped. Increase pressure to 940 psi and held for 5 min. (Worked pipe throughout displacement with 50-325K Ib,but no movement). Bled pressure and floats were not holding. Applied surface pressure,reseated plugs and held 940 psi on floats while WOC. Note:CIP at 01:02 hrs 8/16/15 Cement Stages Stage#9 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 0.0 2,267.0 Yes 275.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 2 6 572.0 450.0 Yes 7.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.7 1,780.0 1,250 DeepCRETE 471.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.93 6.97 0.00 11.00 0.00 50.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOW Additive Type Concentration Conc Unit label Dispersant D185 0.08 gal/sx Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D500 1.0 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,780.0 2,267.0 285 G 63.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control S002 0.6 %BWOC Page 1/1 Report Printed: 12/1/2015 IIIDaily Level: AK Development Daily Drilling Report (No Cos tIP \ 9 CD5-05 CJto+ F'Eai6l Report Number: 4 Rig: DOYON 19 Report Date: 8/15/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 2.79 4.0 0.00 2,285.0 2,285.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 32.51 2.31 9/13/2015 Last Casing String SURFACE,2,267.OftKB Ops and Depth @ Morning Report 24hr Forecast Monitor annulus for pressure, PU 5"DP while waiting on cement. Displace cement, bump plug,check cement float-failure. Hold float equip closed with applied pressure. Close Annular BOP on casing and monitor for pressure increase on the Surface X Conductor annulus. PU DP via the 90'mouse hole while waiting on cement. Last 24hr Summary Finish LD BHA, RU and run 10.75",45.5 lb/ft, L-80, BTC x H563 csg to 2,275'.(Worked through tite spots from 275'-725'md). Circ and condition mud for cementing. Pump Lead and Tail cement,insert cement wiper plug and prep to displace.. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills.Rig and Camp are on high line power. 32°F,Wind NE 8 mph,VIS 0.5 mi,Fog 55.0 Supervisor Title Dave Burley Fld Drlg Supv Dan Lowe Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase `' Op Code : . Activity Code -T-X Trbi Code Trbl Class Start Depth(ftKB) End Depth(ftKB). Operation 00:00 00:15 0.25 SURFAC CASING BHAH P 37.0 0.0 LD SLB PowerPac motor 00:15 01:15 1.00 SURFAC CASING BHAH P 0.0 0.0 Clean&clear floor of BHA tools &equipment. 01:15 02:45 1.50 SURFAC CASING RURD P 0.0 0.0 R/U to run casing.C/O bails on top drive.CIO bushings in rotary table.M/U Volant CRT. 02:45 04:30 1.75 SURFAC CASING PUTB P 0.0 164.0 PJSM.RIH 10-3/4",45.5#,L-80, Casing to 125'(Silver Bullet Shoe,2 jts,Halliburton F/C,&1 jt 10-3/4"BTC csg)Circ and confirm floats functional 04:30 12:00 7.50 SURFAC CASING PUTB P 164.0 1,057.0 Cont.to run 10-3/4"casing f/164' to 1057'.(Ran 19 jts BTC&7 jts Hyd 563 26 total jts., 1 Centek centralizer per jt) Numerous tight spots throughout-most difficult @ 278',390',428',535-547, pump pressure spiking by 100- 250 psi,Large amount of gravel across shakers to 700'.Washed down with 4 bpm 140-170 PSI. 12:00 18:15 6.25 SURFAC CASING PUTB P 1,057.0 2,275.0 Cont.to run 10-3/4"casing f/1057'to 2275'.(Ran 19 jts BTC &34 Hyd 563 total, 1 Centek centralizer per jt)Wash through tight hole f/875'to 920'.Worked through tight spots 920'to 1056', Hole conditions improved below 1100'.Washed casing down w/4 bpm avg.press.150 psi.MU FMC fluted hanger and LJ,Washed down and landed hanger with float shoe @ 2275'&FC @ 2188'. PUW 160K SOW 125K 18:15 18:45 0.50 SURFAC CEMENT CIRC P 2,275.0 2,275.0 Circ&Cond mud at 7-8 BPM, 250-280 psi Latest BOP Test Data Date Corn Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Cosiir • CD5-05 Report Number: 4 pkv Report Date: 8/15/2015 ' Rig: DOYON 19 Time Log ,. . Time P StartTime End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 18:45 ,19:00 0.25 SURFAC CEMENT RURD P 2,275.0 2,275.0 PJSM.RU cement line to Volant CRT. 19:00 21:45 2.75 SURFAC CEMENT CIRC P 2,275.0 2,275.0 C&C mud for cement job. PJSM for cement job. 21:45 22:00 0.25 SURFAC CEMENT SEQP P 2,275.0 2,275.0 Shut down circulating. Line up to pump cement. Flood line with water and pressure test to 3,000 psi. 22:00 00:00 2.00 SURFAC CEMENT CMNT P 2,275.0 2,275.0 Pump 100.1 bbl of 10.5 ppg MudPush II at 4.8-5.2 BPM, 120- 210 psi. Unsting from Volant tool,insert bottom cement plug, sting in with Volant tool. Pump 471.1 bbl of 11.0 LiteCRETE Lead cement plus additives at 5.7 to 7.1 BPM,290-330 psi. Reciprocate pipe 6-8'throughout. Note: Had cement returns to surface after 450 bbl of Lead was pumped. Cement returns to surface after displacement was 275 bbl. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr.:. Type Depth(ftKB) Dens(lb/gal) Vs(s/qt) PV Calc(cP); (Ibf/100ft') (Ibf/100fF) (Ibf/100ft') .:,(Ibf/100ft') MET..(Ib/bbl) (mL t30min) pH (°F) (%) DRILPLEX 2,285.0 10.00 17.0 18.0 21.0 46.0 65.000 19.5 10.9 62.0 DRILPLEX 2,285.0 10.00 18.0 56.0 58.0 93.0 85.000 20.0 10.8 56.0 In1ection Fluid Fluid Source From Lease(bbl) Dest Vendor :.Manifest Number Note Drilling Mud WBM CD5-05 275.0 CD1-01 AES 117 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 115 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 116 CD5-05 Source Well Drill Strings: BHA No.1 - Steerable / Bit Run No. 1 - 13 1/2in,VM-3,5255722 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 114.0 2,285.0 0.75 2-3-WT-A-E-2-RG-TD Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 11 5"HWDP 5 3.000 4 1/2 IF 245.73 6 1/4"Jars 6 1/4 2.250 4 1/2 IF 278.10 9 5"HWDP 5 3.000 4 1/2 IF 553.24 3 7"Flex NMDC 7 2.840 4 1/2 IF 644.67 NM Crossover 8 2.880 6 5/8 REG 648.37 UBHO 8 2.810 6 5/8 FH 650.12 8 1/4"MWD 8 1/4 5.109 6 5/8 FH 677.87 12 1/8"NM Stabilizer 8 2.880 6 5/8 Reg 685.14 A962M3445SP PowerPak 9 5/16 2.125 6 5/8 Reg 714.06 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM - PU Str.Wt Drill Str Wt :SO Str Wt Start(ftKB) (ftKB) >Cum Depth(ft) Cum.Drill Time(hr) Time(hr) (gpm) p (1000lbf) (rpm) SPP(psi) (1000lbf) (10001bf) (1000lbf) Off Btm Tq '; Drill Tq 2,285.0 2,285.0 2,171.00 20.11 Welibores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Page 2/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Cost CD5-05 , �ilps Report Number: 4 Ai�:ks Rig: DOYON 19 Report Date: 8/15/2015 Section Des Size(in) Act Top(ftKB) Act Btm(EKE) Start Date '` End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Casing Strings Csg Des Run Date OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Corn SURFACE 8/15/2015 10 3/4 45.50 L-80 2,267.0 Cement Surface Casing Cement -Started @ 8/15/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-05 SURFACE,2,267.OftKB Had 275 bbl returned to surf Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 0.0 2,267.0 2 572.0 Fluid Class Amount(sacks) -Vol Pumped(bbl) Dens(lb/gal) :< Yield(ft'/sack) Est Top(ftKB) Est:Btm(ftKB) Lead Cement DeepCRETE 1,250 471.1 11.00 1.93 36.7 1,780.0 Tail Cement G 285 63.9 15.80 1.17 1,780.0 2,267.0 Page 3/3 Report Printed: 12/1/2015 • Security Level: AK Development 04*Ng,?, Daily Drilling Report (No Cost CD5-05 Cc�o rllip Report Number: 5 Rig: DOYON 19 Report Date: 8/16/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 3.79 5.0 0.00 2,285.0 2,285.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 32.51 2.31 9/13/2015 Last Casing String SURFACE,2,2i67.0ftKB Ops and Depth @ Morning Report 24hr Forecast Slip and Cut line. Finish weld on Transition nipple and wrap in blanket for propper cooling of Flush stack and LD,weld on wellhead Transition nipple,PU weld remaining 5"DP,Slip&Cut drill line,maintenance on drawworks and brakes, NU BOP and perform Between Well Maint on BOPs. Last 24hr Summary Displace cement, bump plug,check cement float-failure. Hold float equip closed with applied pressure. Close Annular BOP on casing and monitor for pressure increase on the Surface X Conductor annulus. PU DP via the 90'mouse hole while waiting on cement. Bleed off applied pressure.Open Annular, lift Diverter,set slips,and cut 10-3/4"casing for Transition nipple. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills.Rig and Camp are on high line power. 32°F,Wind NE 16 mph,G 23 mph,VIS 10 mi, 54.0 Note:No flow from annulus Cloudy Supervisor Title Dave Burley Fld Dig Supv Dan Lowe Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Latest BOP Test Data Date Com Page 1/3 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report (No Cos CD5-05 illipS Report Number: 5 CollOcoPh Riaskn Rig: DOYON 19 Report Date: 8/16/2015 Time Log Time P Start Time EndTune Our(hr) Phase Op Code Activity Code -T-X 'Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKB) Operation 00:00 01:30 1.50 SURFAC CEMENT CMNT P 2,275.0 2,267.0 Pump 60.1 bbl of 15.8 ppg"G" Tail cement at 2.7 bbl,while reciprocating pipe(PU= 195K, SO= 107K).Slowed pump rate due to pump jacking and cement line whipping in derrick. Casing string stuck 8'high while reciprocating,after 44 bbl of Tail cmt pumped.Continue pumping remaining cmt with returns to surface.(00:10 hrs). Shut down cement pump,un-sting Volant tool from casing and insert top cement plug.Sting in with Volant tool and pump 20.1 bbl of water with cement pump and shut down.Displace with rig pump at 3 -6 BPM,430-680 psi.Had partial returns during first 40 bbl pumped increasing to full returns. Slowed pumps to 3 BPM,430- 450 psi for last 40 bbl of displacement. Bumped plug as calculated at 189.8 bbl pumped. Increase pressure to 940 psi and held for 5 min.(Worked pipe throughout displacement with 50- 325K Ib,but no movement). Bled pressure and floats were not holding. Applied surface pressure,reseated plugs and held 940 psi on floats while WOC. Note:CIP at 01:02 hrs 8/16/15 Note; 10-3/4"Casing set at 2,267' and/2,150.5'tvd 01:30 03:45 2.25 SURFAC CEMENT RURD P 2,267.0 2,267.0 Confer with town.Prep tools and equip for setting emergency casing slips. RD Diverter line remove Knife valve and install blind flange. Casing hanger flutes were located at the Annular element. Pull casing in tension to 235K lb to locate hanger flutes above Annular element. Close Annular BOP and monitor annulus for possible pressure increase. PU 90'mouse hole and set. 03:45 12:00 8.25 SURFAC CEMENT PULD P 2,267.0 2,267.0 PJSM. PU/MU and rack back 56 stds of 5"DP via the mouse hole while WOC. Monitor Surface X Conductor annulus for pressure build-up. Page 2/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Cost CD5-05 aQtafirl'p Report Number: 5 conoRig: DOYON 19 Report Date: 8/16/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code; -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE)''- Operation 12:00 17:00 5.00 SURFAC CEMENT PULD P 2,267.0 2,267.0 PJSM. Continue to PU/MU and rack back 15 stds of 5"DP via the mouse hole while WOC. Monitor Surface X Conductor annulus for pressure build-up. No pressure increase. Install new hydraulic lines under rig floor. 17:00 22:15 5.25 SURFAC CEMENT NUND T Cement- Stuck 2,267.0 2,267.0 Open annulus with no flow or Primary While pressure. Bled off 950 psi from Cementi. casing. Drain riser,LD mouse hole,lift Diverter stack,wash conductor stub out(packed off with 1-3"gravel and cement) center casing and set casing emergency slips. Release surface tension on casing to energize slips with 0.5"casing movement. 22:15 00:00 1.75 SURFAC CEMENT CUTP T Cement- Stuck 2,267.0 0.0 Rough cut 10-3/4"casing. Primary While Backout Landing Jt with 1 turn, Cementi. release Volant tool. LD tools and cut joint from rig floor. Mud Check Data YP Calc ' Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr Type Depth(WE), Dens(lb/gal)` Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ibf/100ft") (Ibf/100ft") (Ibf/100ft') MBT(Ib/bbl( (mL/30min) pH ("F) (%) DRILPLEX 2,267.0 9.80 17.0 7.0 2.0 12.0 19.000 17.5 10.5 55.0 DRILPLEX 2,285.0 9.80 18.0 6.0 3.0 13.0 18.000 17.5 10.6 56.0 Injection Fluid Fluid Source From Lease(bbl.) Dest Vendor Manifest Number Note Cementing Fluids CD5-05 215.0 CD1-01 AES 119 Cement contaminate Cementing Fluids CD5-05 50.0 CD1-01 AES 118 Cement contaminate Drilling Mud WBM CD5-05 250.0 CD1-01 AES 120 CD5-05 Source Well Drilling Mud WBM CD5-05 100.0 CD1-01 AES 109 CD5-05 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des>' Size(m) Act Top(ftKB) Act`Btm(ftKB) 'Start Date r'. End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development t 0 • Daily Drilling Report (No Cost CD5-05 CooPtith Report Number: 6 Rig: DOYON 19 Report Date: 8/17/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 4.79 6.0 0.00 2,285.0 2,285.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 32.51 2.31 9/13/2015 Last Casing String SURFACE,2,267.0ftKB Ops and Depth @ Morning Report 24hr Forecast Nipple up BOPs and RU test equip Inspect weld on wellhead. NU and test BOPE. Perform Between Well Maint on BOPs. Install MPD trip nipple. PU/MU BHA#2-9- 7/8"RSS. Last 24hr Summary Flush stack and LD riser,weld on wellhead Transition nipple, Wait on weld to cool. Perform derrick inspection, Slip&Cut drill line, maintenance on drawworks and brakes, PU remaining 5"DP and MPD elements. General Remarks Weather . Head Count No Incidents, No Accidents,&No Spills.Rig and Camp are on generators. 35°F,Wind NE 17 mph,VIS 6 mi,Cloudy/Fog 54.0 Note:Witness of BOPE test waived by Jeff Jones of AOGCC Note:Rig went off high-line and on generator power at 21:15 hrs,8/17/15. Supervisor Title Dave Burley Fld Drlg Supv Dan Lowe Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(EKE) End Depth(ftKB) Operation 00:00 01:00 1.00 SURFAC CEMENT RURD T Cement- Stuck 0.0 0.0 LD 10.75"LJ,Csg Hanger and Primary While 3.76'cut joint.Set Annular and Cementi. Starting head down onto conductor. 01:00 01:45 0.75 SURFAC CEMENT RURD P 0.0 0.0 RD Volant CRT,bail extensions and elevators.RU to Flush Annular 01:45 02:15 0.50 SURFAC CEMENT WWWH P 0.0 0.0 Flush Annular and riser with stack washer with 6 bpm, 10 psi and 5 rpm.LD stack washer 02:15 02:45 0.50 SURFAC CEMENT NUND P 0.0 0.0 ND riser,Annular BOP and starting head.Prep cellar for welder. 02:45 04:30 1.75 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Welder weld Bell nipple on Primary While casing. SIMOPs PU and install Cementi. 90'mouse hole. 04:30 05:00 0.50 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Welder continue to weld Bell Primary While nipple on casing while LD 1 stand Cementi. of NMDC via 90'MH. 05:00 06:30 1.50 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to install wellhead while Primary While Slip and Cut 75'of drill line. Cementi. 06:30 07:15 0.75 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Finish welding in cellar on Primary While wellhead at 07:10 hrs. Cementi. Note:Pre-heated to 450 deg and held while welding.Cleaned and visually inspected for cracks- none visible. Post heated to 900 F deg evenly. Triple wrapped weld and wellhead with insulation blanket covered with Herculite and set warning cones around cellar. Latest BOP Test Data Date I - Com I. Page 1/2 Report Printed: 12/1/2015 Daily Drilling Report (No Cos Security Level: AK Development \,\ CD5-05 Conoeophitlips Report Number: 6 hia;ks Rig: DOYON 19 Report Date: 8/17/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code -:Activity Code;. -T-X ;Trbl Code`. Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 07:15 09:15 2.00 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Wait on wellhead to cool. Primary While SIMOPs: Remove drawworks Cementi. drum guards and prep for MPI inspection.Remove brake equalizer bar and remove brake linkage shaft. 09:15 11:30 2.25 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:Clean drawworks Cementi. and prep for MPI inspection. 11:30 12:00 0.50 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:Clean and clear Cementi. cellar area and prep tools for NU BOPE. 12:00 14:45 2.75 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:Tuboscope MPI Cementi. brake components-good. 14:45 18:15 3.50 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs: Install new Cementi. Equalizer bar,linkage shaft in drawworks and pin and adjust. 18:15 20:15 2.00 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:Reinstall Cementi. drawworks guards,ODS EZ- Torq.Adjust brakes and change out hose on Crown-O-matic. Bring MPD elements to rig floor. 20:15 00:00 3.75 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:PU remaining 23 Cementi. stands of 5"DP(one with MPD element),via the 90'MH and stand back in derrick. Note: Rig taken off high-line power and put on generators at 21:15 hrs 8/17/15(due to field summer maint)and isolated from facilities per Energy Isolation Policy Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Cort Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft2) (Ibf/100fF) (Ibf/100W) (Ibf/100ftF) MET`(Ib/bbl)`- (mL/30min) pH (°F) (%) DRILPLEX 2,267.0 10.00 22.0 9.0 6.0 19.0 28.000 17.5 10.6 56.0 DRILPLEX 2,267.0 10.00 23.0 8.0 6.0 19.0 28.000 17.5 10.6 57.0 Injection Fluid Fluid `Source From Lease(bbl) Dest Vendor - -:Manifest Number 'Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 121 CD5-05 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB)' Start Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRMI 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Page 2/2 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Cost, ,; CD5-05 cxi�I�S�° Report Number: 7 It3ttsks Rig: DOYON 19 Report Date: 8/18/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 5.79 7.0 0.00 2,285.0 2,285.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 32.51 2.31 9/13/2015 Last Casing String SURFACE,2,267.0ftKB Ops and Depth @ Morning Report 24hr Forecast Finish MU BHA and RIH to pressure test casing to 3,500 psi Finish testing BOPE,install MPD element and pressure test MPD, PU/MU BHA#2-9-7/8"x 11"RSS, RIH and test casing to 3,500 psi, drill out cement shoe track,clean out rat hole and drill 20'of new formation. Perform FIT and drill ahead Intermediate hole section. Last 24hr Summary Test seal on Wellhead and Transition nipple to 1,000 psi-good. NU BOP stack. Perform BWM on BOPs, RU and test BOPE. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills.Rig and Camp are on generators. 34°F,Wind NE 12 mph,VIS 10 mi,Overcast 54.0 Note:Witness of BOPE test waived by Jeff Jones of AOGCC Supervisor >.. Title Dave Burley Fld Drlg Supv Dan Lowe Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 03:00 3.00 SURFAC CEMENT NUND T Cement- Stuck 0.0 0.0 Continue to wait on wellhead to Primary While cool. SIMOPs:LD 90'mouse Cementi. hole,load shed with 4"DP. Check temp of wellhead-165 F deg. Remove one layer of blanket and wait until cool enough to work on. 03:00 03:30 0.50 SURFAC CEMENT PRTS T Cement- Stuck 0.0 0.0 RU and pressure test void in Primary While Transition nipple to 250 psi with Cementi. N2 and hold for 5 min. Increase pressure to 1,000 and hold for 10 min-good.. 03:30 04:30 1.00 SURFAC WHDBOP NUND P 0.0 0.0 Install wellhead,actuator and annulus valves. Test void to 1,000 psi for 10 min-good 04:30 05:15 0.75 SURFAC WHDBOP NUND P 0.0 0.0 Install DSA and Alpine speed head on wellhead.Connect Kill/Annular and Koomey lines. 05:15 07:00 1.75 SURFAC WHDBOP NUND P 0.0 0.0 NU BOPE stack 07:00 11:00 4.00 SURFAC WHDBOP SVRG P 0.0 Perform BWM on BOP stack- Open ram doors and wash out preventer bodies and rams-rig mechanic visually inspected all components including annular preventer-replaced one door seal on blind rams.Close and tighten bolts on ram doors. 11:00 13:00 2.00 SURFAC WHDBOP MPDA P RU MPD Flow box,Flow line, mud bucket return line and trip nipple 13:00 15:00 2.00 SURFAC WHDBOP MPDA P Install secondary annulus valves, hole fill hose,bleeder line, Katch Kan,MU choke line,RU MPD valves and hoses Latest BOP Test Data Date I Com Page 1/2 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Cost CD5-05 Report Number: 7 ConocoPhillips Rig: DOYON 19 Report Date: 8/18/2015 Time Log Time P Start Time End Time Our(hr) ',..Phase. Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE) Operation 15:00 16:30 1.50 SURFAC WHDBOP RURD P 0.0 0.0 RU to test BOPE. Finish installing secondary annulus valves. Set lower Test plug and 5"test joint. Fill stack and lines with water. MU FOSV and Dart floor valves for testing. 16:30 00:00 7.50 SURFAC WHDBOP BODE P 0.0 0.0 BOPE Test:Test with 5"test joint,Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs,Blind rams,auto IBOP,manual IBOP, FOSV,Dart valve,needle valve,choke valves #1 -14, (tighten choke line under rig floor)and HCR Choke and Kill,4"Demco to 250/3,500 psi for 5 min.each- all good.Test all rig gas lines-Test witnessing waived by Jeff Jones of the AOGCC. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,.Corr. ':.Type Depth(ftKB) Dens..(lb/gal). Vis(s/qt) PV Calc(cP) (lbf1100ft') (Ibf/100ft') (Ibf/100ft');. (lbf/1o0ft') MBT;(Ib/bbl) (mL/30min) pH (`F) 1%) DRILPLEX 2,267.0 10.00 22.0 9.0 6.0 19.0 28.000 17.5 11.0 58.0 DRILPLEX 2,267.0 10.00 21.0 10.0 6.0 17.0 26.000 17.5 10.6 56.0 Welibores Wellbore Name Wellbore API/UWI CD5-05 501032071200 section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Page 2/2 Report Printed: 12/1/2015 `\- •. Security Level: AK Development Daily Drilling Report (No Cost 0 CD5-05 conoca iilipss Report Number: 8 Rig: DOYON 19 Report Date: 8/19/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 6.79 8.0 444.00 2,285.0 2,729.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 32.37 2.45 9/13/2015 Last Casing String SURFACE,2,267.0ftKB Ops and Depth @ Morning Report 24hr Forecast Drill 9-7/8"x 11"Intermed hole at 3,235' Drill ahead 9-7/8"x 11"Intermed hole section. Last 24hr Summary Finish testing BOPE and MPD,pull test plug and install WB. PU/MU BHA#2-9-7/8"x 11"RSS, RIH and test casing to 3,500 psi,drill out cement shoe track, clean out rat hole and drill 20'of new formation to 2,305'. Perform LOT to 15.9 ppg EMW and drill ahead Intermediate hole section to 2,729'md. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills.Rig and Camp are on generators. 34°F,Wind NE 7 mph,VIS 4 mi,Overcast/fog 54.0 Supervisor Title Dave Burley Fld Drlg Supv Dan Lowe Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code `. -T-X °Trbl Code Trbl Class Start Depth(EKE) End Depth(ftKB) Operation 00:00 01:30 1.50 SURFAC WHDBOP 'BOPE P 0.0 0.0 Continue to test 3.5"x 6"variable LPRs to 250/3,500 psi. Test Super and Manual chokes to 1,100 psi. Koomey test; IP= 3,200 psi,After close= 1,525 psi, 200 psi recovery 30 sec,full recovery 166 sec, N2-4 bottle average=2,050 psi. Function tested BOPE from the remote panel-good. - Test witnessing waived by Jeff Jones of the AOGCC. 01:30 03:15 1.75 SURFAC WHDBOP MPDA P 0.0 0.0 PJSM. RD Trip nipple and hole fill lines. Install MPD test plug and fill MPD lines with water.Test RCD head,Orbit valve, Lo-Torque#3, 5, 11 and 12 valves to 250/ 1,200 psi.-Good. Flush Poor Boy gas buster with 3 BPM, 160 psi. RD test equipment,pull MPD test plug and RU Trip nipple and hole fill lines. 03:15 04:00 0.75 SURFAC WHDBOP RURD P 0.0 0.0 Pull test plug and install 10"WB. Blow down Choke and Kill lines and manifold.Set 90'MH. 04:00 05:45 1.75 SURFAC CEMENT BHAH P 0.0 143.0 PU BHA#2 to rig floor.MU BHA and RIH w/HWDP to 143' 05:45 06:00 0.25 SURFAC CEMENT TRIP P 143.0 696.0 RIH w/HWDP to 696' 06:00 06:45 0.75 SURFAC CEMENT TRIP P 696.0 2,008.0 RIH w/5"DP from 696'to 2,008'. Calc/Actual=21.8/23.0 bbl displacement. 06:45 07:30 0.75 SURFAC CEMENT COCF P 2,008.0 2,135.0 Wash and ream from 2,008'to 2,158'with 425 GPM,950 psi,60 rpm,3.5K TQ. Tag solid cement set down with 5K lb. PU=130, SO=123, ROT=115K lb. PU to 2,135'. Latest BOP Test Data Date _ Com 5/19/2015 ROPF Test Test with 5"test mint Test Annular to 2.50/2.500 nsi for 5 min_Test 3 5"x 6"variable UPRs Blind rams. auto IROP ma Page 1/4 Report Printed: 12/1/2015 411) Security Level: AK Development h = Daily Drilling Report (No Cost, CD5-05 oecxlhitiaps Report Number: 8 tAx;kiz > Rig: DOYON 19 Report Date: 8/19/2015 Time Log Time P StartTme End Time '.Dur(hr) Phase Op Code Activity Code T X Trbl Code ''Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 07:30 08:15 0.75 SURFAC CEMENT PRTS P 2,135.0 2,135.0 RU and test 10-3/4"csg to 3,500 psi, hold for 30 min and chart record-good. Bleed off pressure and RD test equip. 08:15 09:00 0.75 SURFAC CEMENT COCF P 2,135.0 2,158.0 Wash and ream from 2,135'- 2,158'with 425 gpm,950 psi,60 rpm and 3.5K TQ. 09:00 15:00 6.00 SURFAC CEMENT DRLG P 2,158.0 2,267.0 Drill cement shoe track from 2,158'to 2,267'(FC:2,180'- 2,183', FS:2,265'-2,267'),with 300-650 gpm,430-1,950 psi,40- 70 rpm,2.0-4.5K TQ and 3-20K lb WOB. 15:00 15:15 0.25 SURFAC CEMENT DRLG P 2,267.0 2,305.0 Drill rat hole from 2,267'to 2,285' at 650 gpm, 1,840 psi,70 rpm, 3.5-4.5K TQ. 15:15 15:30 0.25 SURFAC CEMENT DDRL P 2,267.0 2,305.0 Drill 20'of new formation to 2,305'and begin displacing hole to 9.6 ppg LSND mud at 650 gpm, 1,630 psi,70 rpm and 4.0K TQ. 15:30 16:00 0.50 SURFAC CEMENT DISP P 2,305.0 2,305.0 Continue displacing hole to 9.6 ppg LSND and condition mud for LOT. Take SPRs. SPRs-2,135'md,0845 hrs MP#1: 30-90,40-150 MP#2: 30-90,40-150 16:00 16:15 0.25 SURFAC CEMENT OWFF P 2,305.0 2,260.0 Pull back inside casing to 2,260' and flow-chk-static. 16:15 17:00 0.75 SURFAC CEMENT LOT P 2,260.0 2,260.0 PJSM. RU lines and test equip. Perform LOT to 15.9 ppg EMW with 9.6 ppg LSND and 939 psi surface pressure. Shut in and monitor for 30 min. 17:00 17:30 0.50 INTRM1 DRILL RURD P 2,260.0 2,305.0 RD test equip and blow down lines. Wash back down to 2,305' and with 650 gpm, 1600 psi,60 rpm and 4.0K TQ 17:30 19:00 1.50 INTRM1 DRILL DDRL P 2,305.0 2,386.0 Drill ahead 9-7/8"Intermediate hole from 2,305'to 2,386'. PU= 125K,SO=115K, ROT=120K, SPP=1,610 psi. 19:00 19:30 0.50 INTRM1 DRILL CIRC P 2,305.0 2,386.0 Drop 1.25"reamer activation ball and pump down with 250-150 gpm,280-140 psi,30 rpm,2.5K TQ(bit at 2,380'and UR blades at 2,274'). Increase flowrate to 650 gpm, 1,190 psi(460 psi decrease and 660 MWD turbine rpm decrease)indicated flow diverting thru reamer. PU without rotation and tag csg shoe with UR blades with 5K lb. Rotate to bottom under-reaming 11"hole to 2,275'md. Page 2/4 Report Printed: 12/1/2015 \\ • Security Level: AK Development Daily Drilling Report (No Cost . CD5-05 Z //' s \:$ llli Report Number: 8 Ps- Rig: DOYON 19 Report Date: 8/19/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth.(ftKB). End Depth(ftKB) Operation 19:30 00:00 4.50 INTRM1 DRILL DDRL P 2,460.0 2,540.0 Drill 9-7/8"x 11"hole from 2,386 to 2,729'. ADT=5.51 hrs,TVD= 2,487'. PU= 125K,SO= 115K, ROT=120K,TQ on/off=4.5K/ 3.0K ft-lb SPRs-2,305'md, 1550 hrs MP#1: 30-30,40-130 MP#2: 30-30,40-120 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate. Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/1001e) (Ibf/1005) (Ibf/100ft2) (Ibf/100ft2) MBT(lb/bbl) ;(mL/30min) pH (°F) (%) LSND 2,483.0 9.60 43 9.0 21.0 9.0 10.0 10.000 2.5 9.9 9.6 80.0 LSND 2,286.0 9.60 41 8.0 16.0 7.0 8.0 8.000 0.5 9.8 64.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor : Manifest Number -:Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 122 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 123 CD5-05 Source Well Drill Strings: BHA No.2 - Rotary Steerable / Bit Run No. 2 - 9 7/8in,MSI516EBPX,JH7453 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 2,285.0 11,189.0 1.03 16/16/16/16/18 2-4-BT-S-X-I-CT-TD 207 Drill String Components Jts Item Des <OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 112 5", 19.5 lb/ft,S-135, Premium DP 5 4.276 4 1/2 IF 10,462.85 8 HWDP 5 3.000 41/2 IF 10,707.55 6 1/4"Hydraulic Jars 6 1/4 2.250 4 1/2 IF 10,739.92 9 HWDP 5 3.000 41/2 IF 11,015.06 NM Stabilizer 6 13/16 2.880 4 1/2 IF 11,022.02 6 3/4"NMDC 6 3/4 2.875 4 1/2 IF 11,052.79 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 11,065.33 NM Stabilizer(NPFV) 6 13/16 2.812 4 1/2 IF 11,072.33 7 1/4"NMPC 7 1/4 2.875 4 1/2 IF 11,082.43 6 3/4"TeleScope MWD 6 7/8 3.880 4 1/2 IF 11,110.43 6 3/4"ARC 6 3/4 3.880 5 1/2 FH 11,129.26 6 7/8 6 5/8 REG 11,158.00 6 3/4"PowerDrive 6 7/8 2.813 5 1/2 FH 11,158.00 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) ,(ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm)` (10001bf) (rpm) SPP(psi) (1000Ibf) (1000Ibf) (1000Ibf) Off Btm Tq Drill Tq 2,285.0 2,285.0 2,285.0 2,729.0 444.00 5.51 775 11 150 1,700.0 125 122 115 3,500.0 4,500.0 Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB). ',Start Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRMI 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Survey Data MD(ftKB) Inc!'. (°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 2,321.65 38.99 62.63 2,193.25 -205.62 409.96 333.05 2.01 2,416.37 41.33 64.20 2,265.63 -204.09 437.27 387.68 2.69 Page 3/4 Report Printed: 12/1/2015 Security Level: AK Development • Daily Drilling Report (No Cost CD5-05 '' ee�*txiEEi� n Report Number: 8 Rig: DOYON 19 Report Date: 8/19/2015 Suryey Data MD(ftKB) Ind C) Azm(°) TVD(ftKB) VS(ft-)-219030 "NS(ft);.. EW(ft) DLS(°/100ft) 2,511.55 43.80 66.43 2,335.73 .34 464.13 446.17 3.04 2,604.76 46.31 68.70 2,401.58 .91 489.27 507.15 3.20 2,699.25 49.00 70.31 2,465.22 184.77 513.70 572.56 3.11 Page 4/4 Report Printed: 12/1/2015 ► OHO LO 0 0 0 0 0 0 0 O O O 0 O O 0 O CO L()IN COOO N-i N- N- N- N- N- ` COCOOO •-' .N (O CO CO LU LO Ll) LO LO Ll) Ll) LO Ll) Lf) Ln co co L0 L.0 O V N y CO E a- a0-+ H mm , i M1: OL() 00 0000 000 O 0000000000 13 X E m 'E .c co c O N LL) O Ll) CD LO O 4) O Ll) O L() O L() O LO O LO O LO O > d O L I f" 000 NNC6 oPvd' Lli Ln CO (OI- I- eoeo00iO CO 0 E E U m r J UD CL c 0000 0000 000 c) C) d' 00 OOrr Oi- 0 U) .u.)- (D O.Q N M O 0 '� t` y 'a (o a)m 0 N .cn Q Q a) 7 N 0 - N M 't 10 (C Mu) C o f U al o ' O . > ao -- r co 1 L Lo .r 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 O — - ., LU 10 LI) Ll) 1010 � M- d' � � M MMM Ytn (0 C) c Q LO Lt) Lf) 1.0 LO LO Ll) Ll) LO Lt) LO LI) LO Ll) Lt') C) C) 0 E m MMMM M M M M MMM M MMME CORS U m CO r-+ O r N CO V LO 0 is CO 0) O LC) O LO 0 3 -a > 0 y L C r r N N M O O 1 m O a! 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W L r o cn E CD 173 Z n E E m -0 o o.> a y rn Q Q D 0_ 0` a + Q. re O c0 > O O•2.2 C Lo O) CL t 0 � L"L 1-- � O WI o U)i QLn m o x II I- d0 J nN �.., tL N 0 up r \ p in tL 0 o 00 N 66 Ln _> L Ln H J Cl) 0 v — I u j *e r.."1- if T F M , Lo N • � l.L o N 0 - _i___ 0 0 LL If) \\: CO r--: CD x- CID ` x- O 0 to 11 ...� N N 0 LL N Q: co.(I) Q .0 .c Q i f- QJ QJ J . a1 C ti OJ Lo E 00 O0'O (N .- G CO ' O CLn OOON L LO F + d' in 00 co v co Ln .i N M co,-) 3 ~ w 0 o O a) N 2 c0 o t LL co N C7 U _ + CV cn 0 av (J C y .0)0 D O).- w a > 0 VS Cr.) c ' a) a) I- 0 I- � d U E N O i x O w LL. -o a) ca 0 0 0 Q 0 V I . cr O E co 0 F- U) iri N ) �, y m U -di W J o 0 0 0 0 0 0 0 0 (E4 I- N Y 0 II •Y el 0 N N .- o `n N z c �' 3anss3ad E o S w I0 • i CD5-05 Intermediate Casing Well: CD5-05 7 5/8"39# T110 Hyd 563, 29.7#, L-80 BTC-M, 29.7#, L-80, Hyd 563 Date: 8/26/2015 ConocoPhillips Rig: Doyon 19 Alaska,Ina / Depth Jt Number Joints Well Equipment i,and Comments Length Tops ~age 1 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 35.10 s FMC 7.625" fluted hanger .92 35.10 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.35 36.02 Jts 229 to 265 37 Jts 7-5/8", 29.7#, L-80 H563 Casing Dopeless 1489.05 38.37 7-5/8", 29.7#, L80, H563 Box x BTC Pin XO 10.02 1527.42 Jts 132 to 228 97 Jts 7-5/8", 29.7#, L80, BTC-M Casing 4093.46 1537.44 7-5/8", HES-II Cementer(Stage Collar) (Qannik top @ 5,100') 3.02 5630.90 Jts 18 to 131 114 Jts 7-5/8", 29.7#, L80, BTC-M Casing 4819.38 5633.92 Jts 17 to 17 1 Jts 7-5/8", 29.7#, L80, BTC-M B x 7- 5/8", 39#, TN110, HYD 563 P XO Jnt. 43.00 10453.30 Jts 4 to 16 13 Jts 7-5/8", 39#, TNI 10, HYD 563 Casing 548.45 10496.30 7-5/8", 39#, P110, HYD 563, Baffle Adapter Collar 1.39 11044.75 Jts 3 to 3 1 Jts 7-5/8", 39#, TN110, HYD 563 Casing 42.91 11046.14 7-5/8", 39#, C110, HYD 563 Ray Oil Tool Float Collar w/By-pass Adaptor 2.07 11089.05 Jts 1 to 2 2 Jts 7-5/8", 39#, TN110, HYD 563 Casing 83.45 11091.12 7-5/8", 39#,C110, HYD 563 Ray Oil Tools " Silver Bullet" Float Shoe 2.18 11174.57 11176.75 11176.75 11176.75 11176.75 11176.75 TD 9-7/8" Hole at 11,189' MD/7481 TVD (11" Hole to 11,090') 11176.75 Casing Shoe 11,176.7' MD/7480'TVD 11176.75 11176.75 1 Centek 10' up from shoe w/stop rings on Jt#1 11176.75 1 Centek 30' up from pin w/stop rings on Jt#2  11176.75 1 Centek on every joint, floating from #3 to#14 11176.75 1 Centek on every joint, floating from #132 to#155 11176.75 1 Weatherford Tandem Rise Bow Spring on #202 and#203 11176.75 1 Bow spring on every other joint, from #200 to#264 11176.75 11176.75 Total Cents= 38 Centek and 35 Bow Spring 11176.75 11176.75 11176.75 11176.75 11176.75 Remarks: Run-n-Seal on BTC-M, Seal Guard on HYD563 Up Wt 350 K 6,800ft/Ibs BTC-M, 12,400ft/Ibs HYD563 Dopeless, Dn Wt 150 K 19,300ft/Ibs on 39#HYD563 Block Wt 60 K Rig Supervisors:Rick Bjorhus/Dan Lowe/JG Samuell • Cement Detail Report • ,. CD5-05 '-'ito,ocoPhill ps String: Intermediate Stage 1 Job: DRILLING ORIGINAL, 8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Stage 1 8/27/2015 02:19 8/28/2015 00:00 CD5-05 Comment PJSM on cementing. Dowell pump 3 bbls H2O and pressure test lines to 4,000 psi(good),42.3 bbls 12.0 ppg Mud Push, un-sting Volant tool and insert bypass plug,sting in, pump 93 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%inxs), un-sting Volant tool,drop top plug. Dowell displace w/10.1 bbls H20. Rig displace w/493.4 bbls 11.1 ppg LSND at 7.1 bpm,slowing to 3 bpm for final 20 bbl of displacement. Full returns at surface while pumping but not pipe reciprocation. Bump plug, increase pressure to 930 psi(500 psi over)and held for 5 min. Bleed pressure and check floats-not holding. Trap casing pressure, check valve alignment and recheck floats-not holding. Re-bump plug and increase pressure to 910 psi and shut-in. CIP @ 03:36 hrs -1st stage cement job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Stage 1 Cement 500'above 10,152.0 11,177.0 Yes Yes Yes Alpine A Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 992.0 747.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 Cement Detail Report • IP ,6A CD5-05 conocoPhiilips String: Intermediate Stage 2 Job: DRILLING ORIGINAL, 8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Stage 2 8/27/2015 14:14 8/27/2015 14:31 CD5-05 Comment PJSM. Cementers fill lines with water and test to 4,000 psi. pump 41 bbls 12.0 ppg Mud Push,91 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement+ additives(40%inxs). Drop closing plug and cementers displace w/10 bb11.1 ppg LSND,at 7-3 bpm,600-380 psi. Plug would not bump,stop and cycle pump up down pld at ls 1,700H2O.psi,Rig to closedisplace stagew/261 collar.bbls(Fullof returns during displacement). Bled pressure and check if stage collar holding. Flow backand observedand. Pressure ugfinally backbumpeup to 2,200 psi and pressure bled to 1,680 psi in 15 min.Pressure up to 3,150psi and held for 10minutes then 3,600 psi and hold for 10 minutes. Bleed pressure and check for flow-static,no flow. Cement Stages Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Stage 2 4,600.0 5,631.0 Yes 0.0 Yes No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 5 6 737.0 737.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 5,632.0 Drill Bit 5,634.0 6 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,152.0 10,177.0 430 G Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Cost. ...' ., CD5-05 C i ps Report Number: 15 Rig: DOYON 19 Report Date: 8/26/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 13.79 15.0 0.00 11,189.0 11,189.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 30.68 4.15 9/11/2015 Last Casing String INTERMEDIATE, 11,176.8ftKB Ops and Depth @ Morning Report 24hr Forecast Pre-Job Safety Mtg for Cement jobs PJSM, Pump stage 1 cement job and displace,check floats,open cement stage collar and C&C mud and pump second stage cement job. LD 5"DP. Last 24hr Summary Run 7-5/8"casing to 11,175'md.Circ and Cond mud for cementing,PJSM, General Remarks Weather Head Count No Incidents, No Accidents,&No Spills. Rig and Camp are on high line power. 44°F,Wind SW 10 mph,VIS 10 mi,Clear 56.0 Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor JG Samuell Drilling Engineer Will Earhart Drilling Engineer Sara Heskin Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase ';Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 12:00 12.00 INTRM1 CASING PUTB P 3,097.0 9,470.0 Continue to run 7-5/8"29.7 lb/ft, L-80, BTC-M, R3 csg to 9,470' and with 6,900 ft-lb MUT with Run &Seal thread dope. Fill pipe as run.(HES Cementer II installed on top of Jt#131). 12:00 15:15 3.25 INTRM1 CASING PUTB P 9,470.0 9,648.0 Continue to run 7-5/8"29.7 lb/ft, L-80, BTC-M,R3 csg to 9,648' and with 6,900 ft-lb MUT with Run &Seal thread dope. 15:15 19:00 3.75 INTRM1 CASING PUTB P 9,648.0 11,175.0 Continue to run 7-5/8"29.7 lb/ft, L-80,H563,R3, Dopeless csg to 11,175'and with 12,400 ft-lb MUT PU=340K,SO=160K lb. 19:00 00:00 5.00 INTRM1 CEMENT CIRC P 11,175.0 11,175.0 Circ and condition mud from 11.9 ppg to 11.1 ppg and YP from 40 to 20,while increasing flowrate from 1 -6.5 bpm600-420 psi. Reciprocate casing while reciprocating 8-10'until PU= 375K with no pipe movement 3X. Set weight down on hanger and continue to circulate. Mud check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) :Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') P(Ibf/10OfPl :(Ibf/100(F) (Ibf/100fF) MET'(Ib/bbl) r(mL/30min) pH (°F) CA) LSND 11,189.0 11.10 44 9.0 22.0 7.0 10.0 12.000 17.5 9.2 68.0 LSND 11,189.0 11.10 46 14.0 18.0 7.0 10.0 12.000 17.5 9.0 65.0 Injection Fluid Fluid : Source From Lease(bbl) Cast Vendor Manifest Number Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 152 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 153 CD5-05 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Latest BOP Test Data Date I Com : s. 8/10/2015 I ROPF Test.Test with 5"test inint Test Annular to 250/2 500 nsi for 5 min Test 3 5"x 6"variable 11PRs Rlind rams auto IROP ma Page 1/2 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Cost. ;T CD5-05 , li Report Number: 15 OrYnoCitiPhilps p.a. Rig: DOYON 19 Report Date: 8/26/2015 Section Des J Size(in). Act Top(ftKB) '' Act Btm(ftKB) Start Date'' End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Casing Strings Csg Des Run Date OD(in). Wt/Len(Ib/ft) Grade Set Depth(ftKB). -Com INTERMEDIATE 8/26/2015 7 5/8 29.70 L80 11,176.8 Page 2/2 Report Printed: 12/1/2015 Security Level: AK Development 4 • F. Daily Drilling Report (No Costs ' CD5-05 tiips'Arzo, Report Number: 16 Rig: DOYON 19 Report Date: 8/27/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 14.79_ 16.0 0.00 11,189.0 11,189.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 30.68 4.15 9/11/2015 Last Casing String INTERMEDIATE, 11,176.8ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE Flush and freeze protect annulus,finish PU 5"DP,change casing rams to VBRs,RU test equip and test BOPE. RD test equip and PU BHA#3-6.5"RSS. Last 24hr Summary PJSM, Pump stage 1 cement job,displace,bump plug, hold pressure and check floats. Floats leaking. Pressure up, hold floats closed and WOC. Pressure up and open cement stage collar,CBU and pump stage 2 cement job. Drop closing plug,close cement stage collar. WOC,install/test csg packoff seals-good. LD 5"DP. RU to perform annulus LOT. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills.Rig and Camp are on high line power. 41°F,Wind W 22,G35 mph,VIS 10 mi,Clear 56.0 Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor JG Samuel) Drilling Engineer Will Earhart Drilling Engineer Sara Heskin Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code . -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE), Operation 00:00 00:30 0.50 INTRM1 CEMENT CIRC P 11,175.0 11,175.0 Continue to circ and condition mud for cementing, increasing to 7 bpm,430 psi. Final YP=20 00:30 03:30 3.00 INTRM1 CEMENT CMNT P 11,175.0 11,175.0 PJSM on cementing. Dowell pump 3 bbls H2O and pressure test lines to 4,000 psi(good), 42.3 bbls 12.0 ppg Mud Push,un -sting Volant tool and insert bypass plug,sting in, pump 93 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%inxs), un-sting Volant tool,drop top plug.Dowell displace w/10.1 bbls H2O.Rig displace w/493.4 bbls 11.1 ppg LSND at 7.1 bpm, slowing to 3 bpm for final 20 bbl of displacement. Full returns at surface while pumping but not pipe reciprocation. Bump plug, increase pressure to 930 psi(500 psi over)and held for 5 min. Bleed pressure and check floats- not holding. 03:30 04:00 0.50 INTRM1 CEMENT CMNT T Casing/ Float 11,175.0 11,175.0 Trap casing pressure,check Liner Equipment valve alignment and recheck floats-not holding. Re-bump plug and increase pressure to 910 psi and shut-in. CIP @ 03:36 hrs -1st stage cement job. 04:00 04:30 0.50 INTRM1 CEMENT CMNT T Casing/ Float 11,175.0 11,175.0 WOC with 910 psi holding floats Liner Equipment closed. Conduct Pre-Job for laying down drill pipe from the derrick with 90'mouse hole. Latest BOP Test Data Date Com 9/19/2015 f ROPF Test Test with 5"test joint Test Annular to 2.50/2 500 nsi for 5 min_ Test 3 5"x 6"variable UPRs Blind rams auto IROP ma Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs Ax CD5-05 COnciaaPhllbps Report Number: 16 Rig: DOYON 19 Report Date: 8/27/2015 Injection Fluid .':Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 154 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 155 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 156 CD5-05 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start,Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Cement Intermediate Stage 1 -Started @ 8/27/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-05 INTERMEDIATE, 11,176.8ftKB Not reciprocation but full mud returns throughout Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Stage 1 10,152.0 11,177.0 3 992.0 Intermediate Stage 2 -Started @ 8/27/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-05 INTERMEDIATE, 11,176.8ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Stage 2 4,600.0 5,631.0 5 737.0 Fluid Class ' Amount(sacks) Vol Pumped(bbl) Dens(Ib/gat) ) Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Intermediate Cement G 430 15.80 1.16 10,152.0 10,177.0 Page 3/3 Report Printed: 12/1/2015 411 Security Level: AK Development Daily Drilling Report (No Cost, CD5-05 Report Number: 17 ConocoPhiEgps Rig: DOYON 19 Report Date: 8/28/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 15.79 17.0 0.00 11,189.0 11,189.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 30.68 4.15 9/11/2015 Last Casing String INTERMEDIATE, 11,176.8ftKB Ops and Depth @ Morning Report 24hr Forecast RU to test 7-5/8"casing to 3,500 psi RIH and pressure test casing to 3,500 psi. Cut and Slip drill line. Drill out cement shoe track plus 20'of new formation. Displace hole to 9.2 ppg Flo-Pro mud.Take SPRS and flo-chk. Perform FIT to 12.5 ppg EMW.Drill ahead 6-1/2"lateral production hole. Last 24hr Summary Continue to LD 5"DP via 90'mouse hole. RU to perform annulus LOT to 18.4 ppg EMW. Flush 7-5/8"x 10-3/4"annulus with 300 bbl of fresh water,followed by 84 bbl of diesel freeze protect. SI annulus. Change out Saver sub in TD. RU test equip and test BOPE. PU/MU BHA#3, RIH and pulse test MWD. Continue to RIH,tag cement stage collar at 5,633'and drill out. General Remarks Weather Head Count No Incidents, No Accidents,&No Spills. Rig and Camp are on high line power. 36°F,Wind SW 20 mph,VIS 4 mi,Rain 59.0 Note: Witnessing of BOPE test waived by Mr Bob Noble of the AOGCC Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor JG Samuel) Drilling Engineer Will Earhart Drilling Engineer Sara Heskin Drilling Engineer Time Log TiimeP Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:30 1.50 INTRM1 CEMENT PULD T Casing/ Float 0.0 0.0 Continue to LD 5"DP via the 90' Liner Equipment mouse hole from derrick. SIMOPs-RU cementers to 7-5/8" x 10-3/4"annulus,pressure test lines to 2,000 psi. Perform LOT with 11.1 ppg mud. Leak off at 7.5 bbls pumped and 842 surface pressure for 18.4 ppg EMW leak- off. SI and monitor well for 10 min-final SI pressure=532 psi. Pump 300 bbl of fresh water and flush annulus followed by 84 bbl of diesel freeze protect..SI and RD cementers. 01:30 03:30 2.00 INTRM1 CEMENT RURD P 0.0 0.0 Change out Saver sub from 5"to 4"XT39. RU test recording equip. 03:30 04:30 1.00 INTRM1 WHDBOP RURD P 0.0 0.0 Set 4"test plug and test joint. Fill stack and Choke manifold with water. RU to test BOPE. 04:30 07:15 2.75 INTRM1 WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 4"test joint,Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs,Blind rams,auto IBOP,manual IBOP, FOSV, Dart valve,needle valve,choke valves #1 -14, and HCR Choke and Kill,4"Demco to 250/3,500 psi for 5 min.each- all good.Test Manual and Auto choke valves on manifold to 1,100 psi.Tested gas alarms.Test witnessing waived by Bob Noble of the AOGCC. Latest BOP Test Data Date Com 8/2R/2015 ROPF Test Test with 4"test joint. Test Annular to 250/2.500 osi for 5 min Test 3 5"x 6"variable UPRs_ Blind rams auto TROP_ma Page 1/3 Report Printed: 12/1/2015 4110 * Security Level: AK Development Daily Drilling Report (No Costs) CD5-05 fillips Report Number: 17 Rig: DOYON 19 Report Date: 8/28/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 07:15 07:30 0.25 INTRMI WHDBOP BOPE P 0.0 0.0 Koomey test; IP=3,000 psi, manifold press after close= 1,500 psi,250 psi recovery 33 sec,full recovery 180 sec, N2-4 bottle average=1,950 psi. Function tested BOPE from the remote panel-good. - Test witnessing waived by Bob Noble of the AOGCC. 07:30 10:15 2.75 INTRM1 WHDBOP BOPE P 0.0 0.0 Pull 4"test jt and test plug. Set 3 -1/2"test jt and test plug. Fill lines with water.Test Annular to 250/2,500 psi for 5 min,Test 3.5" x 6"variable UPRs and 3.5"x 6" variable LPRs and Blind rams to 250/3,500 psi. Pull 3-1/2"test jt and test plug. Set 4-1/2"test jt and test plug. Fill lines with water.Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs and 3.5"x 6" variable LPRs and Blind rams to 250/3,500 psi. 10:15 11:00 0.75 INTRM1 WHDBOP RURD P 0.0 0.0 Pull 4-1/2"test jt and test plug. Blow down lines and RD test equip. Prep wear rig,run and set 7.125"ID WR. 11:00 14:15 3.25 INTRM1 CEMENT BHAH P 0.0 378.0 MU BHA#3-6-1/2"RSS to 182' 14:15 15:15 1.00 INTRM1 CEMENT PULD P 182.0 1,507.0 PU 4"DP from pipe shed and RIH from 378-1507'.Fill pipe. 15:15 16:15 1.00 INTRM1 CEMENT DHEQ P 1,507.0 1,507.0 Shallow hole test MWD with 224 gpm, 1,030 psi at 1,507'-good. 16:15 21:15 5.00 INTRM1 CEMENT PULD P 1,507.0 5,484.0 PU 4"DP from pipe shed and RIH from 1,507-5,484'.Fill pipe every 3,000'. 21:15 22:15 1.00 INTRM1 CEMENT PRTS P 5,484.0 5,484.0 CBU. RU test equip and test 7- 5/8"csg to 1,000 psi and hold for 10 min-good. Bleed off pressure and RD test equip. 22:15 22:30 0.25 INTRM1 CEMENT PULD P 5,484.0 5,578.0 PU 4"DP from pipe shed and RIH from 5,484-5,578'. 22:30 00:00 1.50 INTRMI CEMENT COCF P 5,578.0 5,633.0 Wash down and tag up on top of cement stage collar at 5,633'md. Rotate and drill collar with 2-10K WOB,40-60 rpm,5.8K TQ PU= 145K,S0=107K,ROT=124K. TQ on/off=5.8K ft-lb Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) <Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft2) (Ibf/100ft2) (lbf/100fF) (Ibf/100fF) MBT(Ib/bbl) (mL/30min) pH (°F) (%) LSND 11,175.0 11.10 60 12.0 22.0 8.0 15.0 20.000 17.5 10.2 48.0 LSND 11,175.0 11.10 55 13.0 21.0 9.0 13.0 15.000 17.5 10.2 54.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 157 CD5-05 Source Well Drilling Mud WBM CD5-05 250.0 CD1-01 AES 158 CD5-05 Source Well Page 2/3 Report Printed: 12/1/2015 v 0.4 • Security Level: AK Development ` ;,, Daily Drilling Report (No Cosh x CD5-05 �lllips Report Number: 17 Rig: DOYON 19 Report Date: 8/28/2015 Drill Strings: BHA No.3 Rotary Steerable / Bit Run No. 3 - 6 1/2in,MDi513,JH8923 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 11,189.0 17,900.0 0.43 10/10/11/11/11 4-1-CT-N-X-I-ER-TD 245 Drill String Components Jts Item Des OD.(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) Drill Pipe 4 3.240 39 XT 0.75 45 HWDP 4 2.750 39 XT 1,350.75 159 Drill Pipe 4 3.240 39 XT 7,926.85 237 Drill Pipe 4 3.340 39 XT 15,402.79 2 HWDP(2 Jts.) 4 2.563 39 XT 15,463.98 1 Drilling Jars-Hydraulic 4.95 2.250 39 XT 15,496.23 3 HWDP(3 Jts.) 4 2.563 39 XT 15,587.73 WEPS PDC Reamer 4 7/8 2.563 39 XT 15,593.48 XO-XT39 Box x 3.51F Pin 4.9 2.750 39 XT 15,595.13 Steel Float Sub w/NPFV 4.9 2.750 3 1/2 IF 15,598.32 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 15,629.11 1 Non Mag Flex Collar 5 2.440 3 1/2 IF 15,660.24 NM Stabilizer 4 3/4 2.250 3 1/2 IF 15,666.56 1 Non Mag Flex Collar 5.05 2.250 3 1/2 IF 15,697.33 Steel Float Sub w/NPFV 4.85 2.250 3 1/2 IF 15,700.48 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 15,733.64 Periscope-LWD(Dir&Logging) 4 3/4 2.125 35 NC 15,758.58 PowerDrive X6 4.95 3.000 35 NC 15,780.24 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM. PU Str.Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft).. Cum Drill Time.(hr) Time(hr) (gpm) (10001bf) (rpm)' SPP(psi) (1000lbf) (1000lbf) (1000lbf) Off Btm Tq Drill Tq 11,189.0 11,189.0 Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development ' ��� Daily Drilling Report (No Costs CD5-05 Conocoifiips Report Number: 18 Rig: DOYON 19 Report Date: 8/29/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-05 Development 16.79 18.0 346.00 11,189.0 11,535.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/12/2015 8/13/2015 34.83 29.13 5.70 9/10/2015 Last Casing String INTERMEDIATE, 11,176.8ftKB Ops and Depth @ Morning Report 24hr Forecast Drilling 6-1/2"lateral Production hole section at 12,000'and Drill ahead 6-1/2"Prod hole section. Last 24hr Summary Continue to RIH picking up DP.Tag up on cement stage collar and drillout from 5,633-4'. Pressure test casing/stage collar to 1,000 psi-good. Continue to RIH picking up 4"DP to 10,898'md.Test csg to 3,500 psi-good.Cut and slip drill line,service rig. Drill out cement shoe track and 20'of new formation. Perform FIT to 12.4 ppg EMW. Drill ahead 6-1/2"production hole section to 11,535' General Remarks Weather Head Count No Incidents,No Accidents,&No Spills.Rig and Camp are on high line power. 41°F,Wind SE 3 mph,VIS 10 mi.Prtly Cloudy 59.0 Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor JG Samuel) Drilling Engineer Will Earhart Drilling Engineer Sara Heskin Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB). Operation 00:00 00:30 0.50 INTRM1 CEMENT DRLG P 5,632.0 5,634.0 Rotate and drill cement stage collar from 5,632-34' with 2-10K WOB,40-60 rpm,5.8K TQ PU= 145K,SO=107K,ROT=124K. TQ on/off=5.8K ft-lb 00:30 01:00 0.50 INTRM1 CEMENT REAM P 5,634.0 5,768.0 Wash and ream down from 5,634'to 5,768',with 200 gpm, 1,260 psi,60 rpm,5.3K TQ,to locate BHA below cementer. 01:00 01:45 0.75 INTRM1 CEMENT CIRC P 5,768.0 5,768.0 CBU at 200 gpm, 1,270 psi,60 rpm,5.5K TQ. 01:45 02:15 0.50 INTRM1 CEMENT PRTS P 5,768.0 5,768.0 Test casing to 1,000 psi for 10 min.-good. 02:15 02:45 0.50 INTRM1 CEMENT PULD P 5,768.0 5,945.0 PU 4"DP from pipe shed and RIH from 5,768-5,945'taking 20K lb in weight. 02:45 03:15 0.50 INTRM1 CEMENT REAM P 5,945.0 6,052.0 Wash and ream down from 5,945'to 6,052'with 190 gpm, 1,190 psi,60 rpm,5.8K TQ. 03:15 08:30 5.25 INTRM1 CEMENT PULD P 6,052.0 10,516.0 PU 4"DP from pipe shed and RIH from 6,052-10,516'hitting tight spot and taking weight. 08:30 09:00 0.50 INTRM1 CEMENT PULD P 10,516.0 10,898.0 PU 4"DP from pipe shed and RIH from 10,516-10,898'. 09:00 10:15 1.25 INTRM1 CEMENT PRTS P 10,898.0 10,898.0 Test casing to 3,500 psi for 30 min.-good. 10:15 11:15 1.00 INTRM1 CEMENT SLPC P 10,898.0 10,898.0 Slip&Cut 60'of drill line and hold After action Review. 11:15 11:45 0.50 INTRM1 CEMENT SVRG P 10,898.0 10,898.0 Service Top Drive-grease and add hydraulic oil 11:45 12:00 0.25 INTRM1 CEMENT SVRG P 10,898.0 10,898.0 Calibrate block height. 12:00 14:15 2.25 INTRM1 CEMENT COCF P 10,898.0 11,044.0 Wash and ream cement stringers from 10,898'to 11,044'with 200 gpm, 1,930 psi,40 rpm. 13K TQ. Tag up on Baffle Adaptor at 11,044' Latest BOP Test Data Date Com 8/28/2015 ROPF Test Test with 4"test joint_Test Annular to 250/2.500 nsi fnr 5 min Test 3 5"x 6"variable tJPRs Blind rams auto IROP ma Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs) CD5-05 Report Number: 18 ConocoPthdlips ,'lw:ka Rig: DOYON 19 Report Date: 8/29/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End,Depth(ftKB) Operation. 14:15 15:00 0.75 INTRM1 CEMENT COCF P 11,044.0 11,089.0 Wash and ream cement from 11,044'to 11,089'with 190 gpm, 1,540 psi,50 rpm. 13.3K TQ.Tag up on Float Collar at 11,089' 15:00 16:00 1.00 INTRM1 CEMENT DRLG P 11,089.0 11,117.0 Wash and ream cement from 11,089'to 11,117'with 220 gpm, 1,770 psi,40 rpm. 13.5K TQ.Drill out btm of Float Shoe at 11,177 16:00 16:30 0.50 INTRM1 CEMENT DDRL P 11,117.0 11,209.0 Drill 20'of new formation from 11,117'to 11,209'with 240 gpm, 3,070 psi,60 rpm, 13.7K TQ. Pump 40 bbl Hi-Vis spacer and Begin displacement of 11.1 ppg LSND mud with 9.2 ppg ProFlo mud systems. 16:30 18:00 1.50 INTRM1 CEMENT DISP P 11,209.0 11,150.0 POOH slowly from 11,209\'to 11,150'displacing 11.1 ppg LSND with 461 bbl of 9.2 ppg Flo Pro. 18:00 18:30 0.50 INTRM1 CEMENT FIT P 11,150.0 11,150.0 RU test equipment and perform FIT to 12.4 ppg EMW. 18:30 19:15 0.75 PROD1 DRILL MPDA P 11,150.0 11,150.0 PJSM.Pull Trip Nipple,and install MPD element 19:15 19:30 0.25 PROD1 DRILL REAM P 11,150.0 11,209.0 Wash and ream back to bottom at 11,209'with 240 gal, 1,930 psi, staging up RPMs from 20-140 with 10.2K to 13.2K TQ,breaking in MPD bearings. 19:30 00:00 4.50 PROD1 DRILL DDRL P 11,209.0 11,535.0 Drill 6-1/2"hole from 11,209'to 11,535'. ADT=3.63 hrs,TVD= 7,497'. PU=225K,SO=125K,ROT= 164K,TQ on/off= 14.0K/13.5K ft -Ib, ECD-9.92 ppg SPRs-11,097'md, 1600 hr MP#1: 20-520,30-820 MP#2: 20-520,30-920 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') (Ibf/100ft2) MBT(lb/bbl) (mU3Omin) pH ("F) (%) Flo Pro NT 11,318.0 9.20 39 7.0 18.0 10.0 12.0 14.000 1.3 9.6 66.0 LSND 11,189.0 11.10 56 15.0 19.0 9.0 14.0 19.000 17.5 10.0 55.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-05 250.0 CD1-01 AES 159 CD5-05 Source Well Drill Strings: BHA No.3 - Rotary Steerable / Bit Run No. 3 - 6 1/2in,MDi513,JH8923 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 11,189.0 17,900.0 0.43 10/10/11/11/11 4-1-CT-N-X-I-ER-TD 245 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) Drill Pipe 4 3.240 39 XT 0.75 45 HWDP 4 2.750 39 XT 1,350.75 159 Drill Pipe 4 3.240 39 XT 7,926.85 237 Drill Pipe 4 3.340 39 XT 15,402.79 Page 2/3 Report Printed: 12/1/2015 Security Level: AK Development = Daily Drilling Report (No Cost _ A CD5-05 Cor000ebiibps Report Number: 18 Rig: DOYON 19 Report Date: 8/29/2015 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 15,463.98 1 Drilling Jars-Hydraulic 4.95 2.250 39 XT 15,496.23 3 HWDP(3 Jts.) 4 2.563 39 XT 15,587.73 WEPS PDC Reamer 4 7/8 2.563 39 XT 15,593.48 XO-XT39 Box x 3.51F Pin 4.9 2.750 39 XT 15,595.13 Steel Float Sub w/NPFV 4.9 2.750 3 1/2 IF 15,598.32 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 15,629.11 1 Non Mag Flex Collar 5 2.440 3 1/2 IF 15,660.24 NM Stabilizer 4 3/4 2.250 3 1/2 IF 15,666.56 1 Non Mag Flex Collar 5.05 2.250 3 1/2 IF 15,697.33 Steel Float Sub w/NPFV 4.85 2.250 3 1/2 IF 15,700.48 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 15,733.64 Periscope-LWD(Dir&Logging) 4 3/4 2.125 35 NC 15,758.58 PowerDrive X6 4.95 3.000 35 NC 15,780.24 Drilling Parameters Flow Rate End Depth Sliding, (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) :: Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (10001bf) (rpm) SPP(psi) (1000lbf) (10001bf).. (10001bf):-..Off Btm Tq Drill Tq 11,189.0 11,209.0 20.00 0.27 250 9 120 2,500.0 225 174 125 13,500.0 14,000.0 11,209.0 11,535.0 346.00 3.90 250 9 120 2,500.0 225 174 125 13,500.0 14,000.0 Wellbores Wellbore Name Wellbore API/UWI CD5-05 501032071200 Section Des Size(in) Act.Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 20 0.0 114.0 3/10/2015 3/10/2015 SURFAC 131/2 114.0 2,285.0 8/13/2015 8/19/2015 INTRM1 9 7/8 2,285.0 11,189.0 8/19/2015 8/29/2015 PROD1 41/2 11,189.0 17,900.0 8/29/2015 9/8/2015 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(`/100ft)., 11,219.19 87.79 123.93 7,482.45 1,778.96 1,693.60 6,974.46 4.24 11,315.42 88.69 126.50 7,485.40 1,864.81 1,638.14 7,053.03 2.83 11,411.52 89.55 129.95 7,486.88 1,952.73 1,578.69 7,128.50 3.70 11,459.09 89.71 132.83 7,487.18 1,997.25 1,547.24 7,164.19 6.06 11,504.66 90.34 136.47 7,487.16 2,040.74 1,515.22 7,196.60 8.11 Page 3/3 Report Printed: 12/1/2015 U5 CD 11111 , CO C3 6 ' ti' :t (N .0tiU U4 CO COL() 't '� NY � � MM! 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Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 36.80_ T � FMC 10-3/4" Casing Hanger .17 36.80 10-3/4", 45.5#, L-80, HYD563 Casing Pup, pin x pin 2.34 36.97 10-3/4", 45.5#, L-80, HYD563 Casing Pup 29.83 39.31 Jts 13 to 54 42 Jts 10-3/4", 45.5#, L-80, HYD563 Dopeless Casing 1717.66 69.14 XO 10-3/4", 45.5#, L-80, HYD563 Casing Box x 10-3/4" BTC-M Pin 9.79 1786.80 Jts 3 to 12 10 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 384.36 1796.59 10-3/4" Ray Oil Tools Float Collar 2.10 2180.95 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 79.25 2183.05 10-3/4" Ray Oil Tools Silver Bullet Float Shoe 2.40 2262.30 2264.70 2264.70 2264.70 2264.70 10 3/4" Shoe at 2265' MD/2156' TVD 2264.70 13 1/2" TD at 2280' MD/2167' TVD 15' rathole 2264.70 2264.70 2264.70 2264.70 2264.70 2264.70 2264.70 2264.70 1 Centek 10' up from shoe w/stop ring above on Jt#1 2264.70 1 Centek 30' up from pin w/stop ring above and below on Jt#2 2264.70 1 Centek 20' up from pin w/stop ring above on Jt#3 2264.70 1 Centek every joint from #4 to #53 floating 2264.70 No centralizer on last Jt 2264.70 53 Total Centek Centralizers 2264.70 2264.70 2264.70 2264.70 2264.70 2264.70 2264.70 Remarks: Use Run&Seal pipe dope on BTC-M, Seal Guard ECF on HYD 563 Up Wt 155 K Avg MU Tq with Volant- 11 k ft/lbs trq for BTC-M & 19400 k ft/lbs trq for Hyd 563 Dopeless Dn Wt 135 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:K.Harding/A. Dorr/J. Engel Cement Detail Report 0:-,i CD5-313 C hinaps ar� String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/24/2015 04:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/29/2015 13:15 6/29/2015 16:30 CD5-313 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"Surface 36.8 2,264.7 Yes Yes Yes Casing Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 3 5 420.0 1,000.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,150.0 Drill Bit 2,280.0 9 7/8 Comment Cement tagged at 2,150 and plugs tagged at 2,166' Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.8 1,776.0 1,399 DeepCRETE 475.8 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 0.00 11.00 6.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,776.0 2,264.7 275 G 57.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 Security Level: AK Development Or • Daily Drilling Report (No Costs) CD5-313 Cc cciPhi€Fips Report Number: 6 AF 1. Rig: DOYON 19 Report Date: 6/29/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 4.71 6.0 0.00 2,280.0 2,280.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 49.83 1.67 8/13/2015 Last Casing String SURFACE,2,264.7ftKB Ops and Depth @ Morning Report 24hr Forecast P/U 5"DP&W.O.C. P/U&rack back 5"DP while W.O.C.R/D Volant&casing equip.L/D landing jt.N/D diverter system.&N/U well head&BOPE. Last 24hr Summary Cont.to work tight hole w/casing to 929'. RIH w/casing f/929'to 2,195'. M/U hanger&landing jt&land casing @ 2,265'.Circ&cond for cement job.Cement casing as per Dowell.Shut in annulus.W.O.C.SIMOPS-P/U 5"DP General Remarks Weather Head Count No Incidents&No Accidents 67°F,Wind NE @ 3 mph,VIS 10 mi,Cloudy 55.0 Rig&Camp on high line power. Supervisor Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuel) Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 02:00 2.00 SURFAC CASING PUTB T Hole Undergau 884.0 929.0 Cont.to work tight hole f/884'to Conditions ge/Tight 929'.Pumping 4.5-6 bpm @ 120 Ho. 140 psi.Work with casing with 1/4 turn increments.Work casing while rotating @ 5 rpm @ 5 k trq. Hole continued to have fine& large gravel with occasional wood.Free P/U wt 95 k.Casing broke free @ 929' 02:00 07:45 5.75 SURFAC CASING PUTB P 929.0 2,225.0 RIH hole with casing f/929'to 2,225'while pumping 6-4.5 bpm @ 200-120 psi Tight hole @ 1,242', 1,289, 1,380', 1,490 07:45 08:15 0.50 SURFAC CASING HOSO P 2,225.0 2,265.0 M/U casing hanger&landing jt. Land casing on hanger @ 2,264.7'PU wt 155 k/SO wt 135 k 08:15 08:30 0.25 SURFAC CEMENT CIRC P 2,265.0' 2,265.0 Circ&cond w/4 bpm @ 200 psi SIMOPS-PJSM on R/U cementing equipment 08:30 09:00 0.50 SURFAC CEMENT RURD P 2,265.0 2,265.0 B/D top drive&R/U cementing equipment lines&hoses. 09:00 13:15 4.25 SURFAC CEMENT CIRC P 2,265.0 2,265.0 Circ&cond mud for cement job w/4-8 bpm @260-510 psi. SIMOPS-PJSM for cement job Latest BOP Test Data Date I Com Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs CD5.313 flips Report Number: 6 ConocciPhiRig: DOYON 19 Report Date: 6/29/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 13:15 16:30 3.25 SURFAC CEMENT CMNT P 2,265.0 2,265.0 Surface cement job.Dowell pump 1.1 bbls H2O&test lines to 3000 psi(good), Dowell pump 74.6 bbls 10.5 ppg Mud Push II,Drop bottom plug,Dowell pump 475.8 bbls total 11.0 ppg DeepCRETE 1.91 ft3/sk yield lead cement @ 4 -7 bpm/200-400 psi.Dowell pump 57 bbls 15.8 ppg 1.17 ft3/sx Tail Design cement @ 4 bpm/100-250psi.Drop top plug. Dowell pump 20 bbls H2O @ 4 bpm/90 psi. Rig displace w/190 bbls/1905 stks©95%of 10.0 ppg DrillPlex spud mud.Initial 8 bpm @ 500 psi&Final 3 bpm @ 420 psi.Increase to 580 psi over @ 1000 psi&hold for 5 min. Check floats(not holding). Pressure up on floats to 230 psi for @.5 bbls. Reciprocated pipe 20'stroke with full returns 118 bbls good cement back to surface.CIP @ 16:24 hrs. 16:30 16:45 0.25 SURFAC CEMENT RURD P 0.0 0.0 Flush riser&function bag.Close bag&monitor annulus. 16:45 00:00 7.25 SURFAC CEMENT PULD P 0.0 0.0 R/D 10 3/4"elevators&bails. R/U to P/U 5"DP.P/U&rack back 5"DP via mouse hole& tugger.SIMOPS-W.O.C.& monitor psi on annulus. @ 20:35 hrs pressure @ 45 psi, bleed off 1 gal to 30 psi. Pressure immediately increased to 40 psi. Bleed off 1/2 gal to 30 psi& monitor.As of 24:00 hrs pressure holding @ 35 psi on annulus&0 psi on casing floats.Max psi observed on annulus 52 psi @ 22:30 hrs. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100fti (Ibf/100ft2) (Ibf/100ft') (lbf/100ft2) MBT(Ib/bbl) (mL/30min) pH (°F) (%) DRILPLEX 2,280.0 10.00 17.0 11.0 3.0 11.0 16.000 16.5 10.1 68.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-313 1250.0 CD1-01 AES 720,21,22,23,24 CD-313 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Page 2/3 Report Printed: 12/1/2015 :1.., • s 1 Security Level: AK Development Daily Drilling Report (No Costs) A CD5-313 illi Report Number: 6 F,#:3shs Rig: DOYON 19 Report Date: 6/29/2015 Casing Strings Csg Des Run Date _ OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Corn SURFACE 6/29/2015 10 3/4 45.50 L-80 2,264.7 53 Centek Centralizers. 1 per jt to jt 53 Cement Surface Casing Cement -Started @ 6/29/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-313 SURFACE,2,264.7ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface Casing Cement 36.8 2,264.7 3 420.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(lb/gal) Yield(fP/sack) Est Top(ftKB) Est Btm(ftKB) Lead Cement DeepCRETE 1,399 475.8 11.00 1.91 36.8 1,776.0 Tail Cement G 275 57.0 15.80 1.17 1,776.0 2,264.7 Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Costs) 02, 0 CD5-313 co oaoPhiflips Report Number: 7 FRxka Rig: DOYON 19 Report Date: 6/30/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 5.71 7.0 0.00 2,280.0 2,280.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 50.83 0.67 8/14/2015 Last Casing String SURFACE,2,264.7ftKB Ops and Depth @ Morning Report 24hr Forecast N/U MPD equipment Weld cap on conductor x 10 3/4"annulus.N/U well head&BOPE. Test BOPE. Last 24hr Summary P/U&rack back 5"DP while W.O.C.&monitor psi on annulus.R/D Volant&casing equip.Drain riser&observe flow.Fill riser w/mud&monitor psi.Cont.to P/U DP.Drain&flush riser. N/D diverter sytem&speed head.Prep conductor x 10 3/4"annulus for welder.SIMOPS-R/U tiger tank&2"hardline. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 64°F,Wind SE @ 6 mph,VIS 10 mi,Cloudy 55.0 Rig&Camp on high line power. Supervisor Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuel) Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 05:45 5.75 SURFAC CEMENT PULD P 0.0 0.0 P/U 5"DP&rack back in derick via mouse hole&tugger(58 stands total).SIMOPS-W.O.C. &monitor psi on annulus. SIMOPS-4:30 hrs N/D diveter line down stream of Knife valve. 00:00 hrs=35 psi, 1:00 hrs=30 psi,3:00 hrs=29 psi,5:30 hrs= 25 psi 05:45 06:15 0.50 SURFAC CEMENT SVRG P 0.0 0.0 Service rig&inspect derrick 06:15 08:00 1.75 SURFAC CEMENT PULD P 0.0 0.0 P/U 5"DP&rack back in derick via mouse hole&tugger(70 stands total).SIMOPS-W.O.C. &monitor psi on annulus 08:00 08:15 0.25 SURFAC CEMENT SFTY P 0.0 0.0 Safety Stand Down(Finger Injury Doyon 25) 08:15 09:00 0.75 SURFAC CEMENT PULD P 0.0 0.0 P/U 5"DP&rack back in derick via mouse hole&tugger(74 stands total).R/D single jt elevaotrs.SIMOPS-W.O.C.& monitor psi on annulus 09:00 10:00 1.00 SURFAC CEMENT RURD P 0.0 0.0 R/D Volant CRT&cement lines. B/D.Clean Volant&L/D via beaver slide. 10:00 11:00 1.00 SURFAC CEMENT OWFF P 0.0 0.0 Open bag&drain riser.Monitor flow in cellar.Well flowing between conductor x 10 3/4" annulus @.28 bbls/hr.SIMOPS- P/U 5"DP&rack back in derick via mouse hole&tugger(79 stands total) 11:00 17:45 6.75 SURFAC CEMENT OWFF T Geological Other 0.0 0.0 Fill riser with Drill Plex Spud Mud &close bag.Monitor pressure on 2"on speed head.Pressure increase f/0 to 20 psi in 6 hrs. SIMOPS-P/U 5"DP&rack back in derick via mouse hole&tugger (103 stands total) Latest BOP Test Data Date I Corn Page 1/2 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Costs 0 s;, CD5-313 ilipls Report Number: 7 Rig: DOYON 19 Report Date: 6/30/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 17:45 20:00 2.25 SURFAC CEMENT RURD P 0.0 0.0 Decision made to proceed with well program&let well flow during operations to tiger tank. Drain riser, UD landing jt&LID mouse hole.Flush riser&bag w/H20 20:00 00:00 4.00 SURFAC CEMENT NUND P 0.0 0.0 N/D drain lines,riser,bag,&FMC speed head.Prep conductor x 10 3/4"annulus hanger flutes for welder.SIMOPS-R/U tiger tank &2"hard lines. Mud Check Data YP Calc Gel(105) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Cori. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ftF) (Ibf/100ft') (Ibf/100ft2) (Ibf/100fti) MBT(Ib/bbl) (mL/30min) pH ('F) (%) DRILPLEX 2,280.0 10.00 12.0 5.0 3.0 8.0 12.000 16.5 10.0 67.0 DRILPLEX 2,280.0 10.00 13.0 3.0 3.0 8.0 12.000 16.5 10.0 67.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-313 490.0 CD1-01 AES 725,26 CD-313 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Page 2/2 Report Printed: 12/1/2015 Security Level: AK Development 0 0. Daily Drilling Report (No Costs) CD5-313 4Cono illips Report Number: 8 Ar5sw Rig: DOYON 19 Report Date: 7/1/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 6.71 8.0 0.00 2,280.0 2,280.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 50.90 0.60 8/14/2015 Last Casing String SURFACE,2,264.7ftKB Ops and Depth a@ Morning Report 24hr Forecast Drilling cement shoe track Drill out cement shoe track and 20'of new hole. CBU and perform LOT. Drill ahead 9-7/8"Pilot hole. Last 24hr Summary Weld cap on conductor x 10 3/4"annulus hanger flutes. N/U well head&test. N/U BOPE.N/U MPD equipment.Test BOPE with 5"and 3-1/2"test joints. PU/MU BHA#3,RIH,shallow test MWD.RU and pressure test 10-3/4"casing to 3,500 psi. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 61°F,Wind SE @ 6 mph,VIS 10 mi,Cloudy 55.0 Rig&Camp on high line power. Note:BOPE test witnessing waived by Bob Noble of AOGCC Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor Joseph Engel Rig Engineer JG Samuell Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:30 1.50 SURFAC CEMENT NUND T Geological Other 0.0 0.0 Weld cap on conductor x 10 3/4" annulus hanger flutes.SIMOPS- R/U double annulus valves on well head. Prep BOPE 01:30 02:15 0.75 SURFAC WHDBOP NUND P 0.0 0.0 N/U well head&test seals to 1000 psi for 10 min(good). SIMOPS-PJSM on N/U BOPE 02:15 03:00 0.75 SURFAC WHDBOP NUND P 0.0 0.0 NU BOPE&Rotating head. 03:00 07:00 4.00 SURFAC WHDBOP MPDA P 0.0 0.0 N/U MPD equipment.Flow box, flow line,trip nipple,&orbit valve. MU 2 RCD elements on 5"DP& rack back in derrick.NU hole fill line and Katch-Kan. 07:00 08:00 1.00 SURFAC WHDBOP RURD P 0.0 0.0 RU to test BOPE.Set lower Test plug and 5"test joint. Fill stack and lines with water. RU FOSV and Dart valves for testing. Latest BOP Test Data Date Com 7/1/2015 ROPE Test. Test with 5"test joint.Test Annular to 250/2.500 nsi for 5 min. Test 3.5"x 6"variable UPRs and 3.5"x 6"variable I_PRs . Page 1/3 Report Printed: 12/1/2015 talk • Security Level: AK Development Daily Drilling Report (No Costs CD5-313 €uxcotiil4ips Report Number: 8 hEsks Rig: DOYON 19 Report Date: 7/1/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(EKE) Operation 08:00 11:30 3.50 SURFAC WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 5"test joint,Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs and 3.5"x 6" variable LPRs to 250/3,500 psi. Test choke valves#1 -14 and needle valve to 250/3,500 psi for 5 min., HCR Choke and Kill,4" Demco,4"FOSV,dart&needle valves,HCR choke&kill to 250/3500 psi for 5 min.-good. Koomey test; IP=3,000 psi,After close=1,650 psi,200 psi recovery 30 sec,full recovery 156 sec, N2-4 bottle average=2,000 psi. Function tested BOPE from the remote panel-good.Tested gas alarms. - Test witnessing waived by Bob Noble of the AOGCC. BOPE Test:Test with 3.5"test joint,Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs and 3.5"x 6" variable LPRs and Blind rams to 250/3,500 psi. - Test witnessing waived by Bob Noble of the AOGCC. 11:30 12:00 0.50 SURFAC WHDBOP BOPE P 0.0 0.0 Pull 5"test jt and test plug. Set 3 -1/2"test jt and test plug.Fill lines with water. 12:00 14:30 2.50 SURFAC WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 3.5"test joint,Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6" variable UPRs and 3.5"x 6" variable LPRs and Blind rams to 250/3,500 psi. - Test witnessing waived by Bob Noble of the AOGCC. 14:30 16:15 1.75 SURFAC WHDBOP MPDA P 0.0 0.0 PJSM.Fill MPD lines with water. Test RCD head,Orbit valve,Lo- Torque valve and Choke valves 3,4,5 and 7 to 200/1,200 psi.- Good.RD test equipment and blow down TD. 16:15 17:15 1.00 SURFAC WHDBOP RURD P 0.0 0.0 Blow down MPD equipment and pull MPD test plug. Install wear ring. 17:15 17:45 0.50 SURFAC CEMENT BHAH P 0.0 0.0 PU BHA#3 to rig floor.PU and set 90'mouse hole 17:45 18:15 0.50 SURFAC CEMENT SVRG P 0.0 0.0 Service TD and drawworks. 18:15 21:30 3.25 SURFAC CEMENT BHAH P 0.0 857.0 MU 9-7/8"BHA#3 to 857'. 21:30 23:00 1.50 SURFAC CEMENT TRIP P 857.0 1,982.0 RIH from 857'to 1,982'with 5" DP 23:00 23:15 0.25 SURFAC CEMENT DHEQ P 1,982.0 1,982.0 CBU at 675 gpm, 1,780 psi,30 rpm,2.9K TQ,ROT=145K and shallow test MWD-good. Page 2/3 Report Printed: 12/1/2015 . i Security Level: AK Development 4 Daily Drilling Report (No Costs) CD5-313 eV Ccxnosc 'ttitFpis Report Number: 8 Rig: DOYON 19 Report Date: 7/1/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X. Trbl Code Trbl Class Start Depth.(EKE) End Depth(ftKB) Operation 23:15 00:00 0.75 SURFAC CEMENT PRTS P 1,982.0 1,982.0 BD TD and rig up for csg test. Test 10-3/4"csg to 3,500 psi and hold for 30 min. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth.(ftKB) Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (lbf/100(r) (lbf/100ft') (lbf/100fP) (Ibf/10OfP) MBT(Ib/bbl) (mL/30min) pH ("F) )%) DRILPLEX 2,280.0 10.00 12.0 5.0 3.0 8.0 12.000 16.5 10.0 67.0 DRILPLEX 2,280.0 10.00 12.0 6.0 3.0 8.0 12.000 16.5 10.0 66.0 Drill Strings: BHA No.3 - Xceed RSS / Bit Run No. 2 - 9 7/8in,SDi516,JK1345 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 2,280.0 15,946.0 0.98 16/16/16/16/16 2-3-CT-N-X-3-WT-TD 6 Drill String Components Jts Item Des OD(in) i. ID(in) : Top Conn Sz(in) I. Top Thread E. Cum Len(ft) 9 7/8"Ghost Reamer 6 3/4 3.000. 4 1/2 IF 7.59 19.50 DPS 6 3/4 4.276 4 1/2 IF 3,151.92 HWDP 6 3/4 3.000 4 1/2 IF 3,397.34 6 1/4"Hydraulic Jars 6 3/4 2.688 4 1/2 IF 3,429.07 HWDP 6 3/4 3.000 4 1/2 IF 3,796.15 Float Sub(NPFV) 6 3/4 2.813 4 1/2 IF 3,799.38 Float Sub(NPFV) 6 3/4 2.875 4 1/2 IF 3,802.29 7 1/4"Flex NMDC 6 3/4 2.810 4 1/2 IF 3,894.05 6 3/4"SonicScope 6 3/4 5.157 4 1/2 IF 3,929.41 6 3/4"TeleScope MWD 6 3/4 3.880 5 1/2 FH 3,957.16 EcoScope w/8 1/4"Stabilizer 9 3/4 2.000 5 1/2 FH 3,983.24 6 3/4"Xceed 9 3/4"Stabilizers 9 3/4 5.160 5 1/2 FH 4,008.32 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(EKE) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gPm) (1000lbf) (rpm) SPP(psi) (1000lbf) (1000Ibf) (1000lbf) Off Btm Tq Drill Tq 2,280.0 2,280.0 Wellbores' Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) : Act Top(ftKB) Act Btm(ftKB) `-Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Page 3/3 Report Printed: 12/1/2015 ' 000 U) U3U) 0U) 0 U) 0U) CnbC (n (n0 III NOCn MNr r00 CA O) CO CO CO CO N- r.... 0- Y 'F 00Mt` NN- N- tit` t` CO CO CO CO CDCDCOCOCO fn - C C2 O CJ- d d E mm X L f0 c 3 C6 I- - O Cn 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 -0 COM X GC 'E • U) c o N LO 0 LO O Cn 0 Ln O LO 0 LCD O Ln O CO O Ln O CO 0 > a) • 0. •L OOO c- NNM Md' tet• tf) LUCO (Ot- N- CbC66) 6) O m1-0 E E in O N (n a cncnoUn cn000 000 0 0 N- MCA01- N- CO CA CA CO CO ' CA N Cl) i- 3 1- p'Q rr- NM � CU CON- CO CO 0 -O- 0 N .O E a)m SZ E E N ,-- NM V LUCDN- M 6) OT- N c o f N (1 g r r r > CL CI F- L Y ^ CD V/ 0 r i 0 61, 0C Jo Otn00 U) U) 0 O o _00 't=y .( d• V co N N 0 0 0 CO N O Y (n O 0) n c o up in Ln in in in up In in up LO d' d' ' ' O 0 E (n E m - MMMM M M M M MMM CO MMM E mm co =• coC) - cn L C O � NM � � Mti 0000 - CD ep 0 -a co F— 2 > m 0 0 (6 O up O O O O O U3 O 140 O O O U0 O U3 U3 O O U3 0 0 0 0 0 0 0 0 0 0 0 N E ' N CV01COC) CO Ono r6) OO ti CnUnd' CONMM000) OrNd' 0O0 - 1- C4 OV) rC'O (6 OOOrN MM ' up CON- 0O00 - N M ' COI- 00 coo ON M ' to CU 73.0 C C (J O O- r r r r r r r r r r r N N N N N N N N N CO CO CO CO CO E cum E (,) � M (nt— CAr0d' U) C N- CO CAO NCO - U) CON- O0) 0 NCo -a- up o O E e- r r r r r r r N N N N N N N N N N CO M CO CO CO M CO O SCD 15• i5 65 a F7 IIu:olo:::mim::mmm 1MC) / a :0 0c� " - co(0 0 V � 11111 � ., ~ N � - ° �� �sA � QN i rioiiiiiiiiiiiiiiiiiiiiiiiiiiinii N tl ON C2J JJ 2 d LL a. 63 o y - c. c) - - •- � I��IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII c m ooCp � ay N m F- c. c) 7 0 a_ Z JQCO 3 00 00 up iIIIIIIIIIIIIHhIIHllIIII1IIIII11 .,_ S Cn � ' , a_ Ce 0 7 73 = N �_ .i l�illllllllllllllllllllllh!11111110 c W CI) U E E N rn > E > % - 0 00• a) Cl) . 3 3 � � � .� � a- U) Z a n. a o -0m + 03 in Ce U o > o o .� E in 00 CV 0 _ U_ m o w C w CD Q.•- coo m et x I I tL Ii !62 -(151 m LOO 0 II ,w 0 1- N CA N M y .1....1... v 5 Li_ N S?_- in _o L F\- 0_J 0_J _I .0 O o C6 OJ In E 00 000 Tr N 2 m 0) 0. O COci OOO r- Cv 7.. O O o LH MH +' M0n O UJ n CD ~ N z co U _ a� a C _c N L y i m N Q n C • 0)C) D • 0).� G) 7 > 0 ' co(5 N , A N O F- 12 F- N m w V > E O 0 L x C O 7) n N o 0 EL CA j y' din c O I0 ° _ V) D � � y • r' 0 W J y c �O LL E o 0. CO Y C CU S o E 0. N U Fn F— r co . O co >+ O m U Y W J o 0 0 Lo o o F- N Y 0 II - r) r) N N N ? _ MInss3Id E _ m m •L o 2 o 0 S W 'U • o CD5-313 7-5/8"Intermediate Casing Well: CD5-313 ConocoPh�llips 29.7#L-80 BTC-M & Hyd 563 Date: 7/25/2015 Alaska,Inc. Rig: Doyon 19 Num FIlIP'• Depth Jt Number Well Equipment Description and Comments Length Tops of Jts Page 1 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.38 = � FMC 7.625" fluted hanger _ .85 34.38 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.32 35.23 Jts 276 to 319 44 Jts 7-5/8", 29.7#, L-80 H563 Casing Dopeless 1768.72 37.55 7-5/8", 29.7#, L80, H563 Box x BTC Pin XO 10.03 1806.27 Jts 169 to 275 107 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 4520.24 1816.30 7-5/8", HES-II Cementer (Stage Collar) (Qannik top 5,801') 3.02 6336.54 Jts 4 to 168 165 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 6950.57 6339.56 7-5/8", 29.7#, L-80, BTCM, Baffle Adapter Collar 1.52 13290.13 Jts 3 to 3 1 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 42.67 13291.65 7-5/8", 29.7#, L80, Weatherford Float Collar w/By-pass Adaptor 1.33 13334.32 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC-M Casing BTC-M 83.68 13335.65 7-5/8", 29.7#, L80, Ray Oil Tools " Silver Bullet" Float Shoe 2.20 13419.33 Bottom of shoe >>> 13421.53 13421.53 13421.53 13421.53 13421.53 13421.53 TD 9-7/8" Hole at 13,432' MD/7,347 TVD (11" Hole @ 13,334') 13421.53 Casing Shoe 13,421' MD/7,347' TVD 13421.53 13421.53 1 Centek 10' up from shoe w/stop rings on Jt#1 13421.53 1 Centek 30' up from pin w/stop rings on Jt#2 13421.53 1 Centek on every joint, floating from #3 to#13 13421.53 1 Bow spring on every joint, over collar from #168 to#193 13421.53 1 Tandem Bow spring on every joint, over collar from #264 to#266 13421.53 1 Tandem Bow spring on every other joint, over collar from #268 to#317 13421.53 13421.53 13421.53 13421.53 13421.53 13421.53 13421.53 13421.53 Remarks: Shoe track Baker Locked to pin of jt#4 Up Wt N/A K Run&Seal on the BTC-M, No thread compound on Dopeless Hyd 563 Dn Wt 145 K M/U Trq BTCM =to diamond Block Wt 60 K M/U Trq Hyd 563 Dopeless= 12.4 k ftlbs/trq Rig Supervisors: K. Harding/ A. Dorr • Cement Detail Report • CD5-313 Conoco Masks imps' String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 6/24/2015 04:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 7/25/2015 17:00 7/25/2015 22:45 CD5-313 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 7 5/8"Casing 12,872.0 13,421.6 No Yes Yes Cement Shoe Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 640.0 1,140.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 13,285.0 Drill Bit 13,432.0 6 3/4 Comment PJSM on cementing. Dowell pump 3 bbls H2O&pressure test lines to 4000 psi(good),43 bbls 12.0 ppg Mud Push,drop bypass plug,50.8 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement,drop landing plug.Dowell displace w/20 bbls H20.Rig displace w/594 bbls @ 5952 stks of 11.1 ppg LSND.Bump plug w/4 bbls over calculated. ICP=6 bpm @ 650 psi&FCP 3 bpm @ 640 psi. Pressure up 500 psi over to 1100 psi&hold for 5 min.Check floats(good)No returns &no reciprocation while cementing.CIP @ 20:00 hrs Lost 700 bbls mud on 1st stage cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 15.8 ppg Qannik 12,872.0 13,421.0 290 G 50.9 Slurry Blend Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 5.00 1,000.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Iscolate Qannik 5,301.0 6,336.0 No Yes No Cement Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 3 7 270.0 1,480.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,315.0 Drill Bit 6,339.0 6 3/4 Comment Dowell pump 50 bbls 12.0 ppg Mud Push, 90.2 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement,drop closing plug.Dowell displace w/20 bbls H20. Rig displace w/273 bbls @ 2733 stks of 11.1 ppg LSND.ICP=7 bpm @ 550 psi&FCP 3 bpm @ 380 psi.Pressure up 1480 psi&close stage collar,cont.to 2000 psi&hold for 5 min.Check floats(good)50% returns while pumping mud push&cement. 100%returns while displacing.CIP @ 22:40 hrs Lost 74 bbls on 2nd stage cement job Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 15.8 ppg Qannik 5,301.0 6,336.0 436 G 90.2 Slurry Blend Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 4.25 1,000.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 • Daily Drilling Report (No Costs Of i, CD5-313 Security Level: AK Development ihris Report Number: 32 conocoPh Alaska Rig: DOYON 19 Report Date: 7/25/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 30.71 32.0 0.00 13,432.0 13,432.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 48.09 3.41 8/11/2015 Last Casing String INTERMEDIATE, 13,421.6ftKB Ops and Depth @ Morning Report 24hr Forecast UD 5"DP Set pack off&test.Cut&slip drill line. L/D 5"DP.SIMOPS- Perform annular LOT&freeze protect10 3/4"x 7 5/8"annulus. Last 24hr Summary Cont.run casing&land on hanger @ 13,421'.Attepnt to circ w/no returns.Pump 1st stage cement job as per Dowell.Open stage collar.Circ B/U. Pump 2nd stage cement as per Dowell. L/D Volant&landing jt. General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 46°F,Wind N 8 mph,VIS 5 mi,Fog in Morning 55.0 Rig&Camp on high line power. Supervisor Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuel) Drilling Engineer Time Log Time P Start lime End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 15:15 15.25 INTRM2 CASING PUTB P 8,046.0 13,387.0 Run 7 5/8",29.7#,L-80,BTC casing f/8,046'to 13,387'as per detail w/power tongs.Fill pipe every jt wNolant.No returns while running casing.(Tight hole 11,110'&11,534',60-80 k hookload to break over&Various tight spots through out shales) Lost 570 bbls total mud running casing. 15:15 15:45 0.50 INTRM2 CASING HOSO P 13,387.0 13,421.0 M/U hanger&landing jt&land on hanger @ 13,421' 15:45 16:30 0.75 INTRM2 CEMENT CIRC P 13,421.0 13,421.0 Attempt to circ w/2-4 bpm @ 150-690 psi.(partial to no returns)Not able to reciprocate pipe Lost 100 bbls mud while circulating. Latest BOP Test Data Date Com 7/15/2015 ROPF Test Test with 5"test joint_Test Annular to 250/2.500 nsi for 5 min.Test choke valves#1 - 14 and needle valve to 250/3.500_. Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs CD5-313 Conocc lailliips Report Number: 32 Af Aa Rig: DOYON 19 Report Date: 7/25/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 16:30 20:30 4.00 INTRM2 CEMENT CMNT P 13,421.0 13,421.0 PJSM on cementing. Dowell pump 3 bbls H2O&pressure test lines to 4000 psi(good),43 bbls 12.0 ppg Mud Push,drop bypass plug,50.8 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement, drop landing plug.Dowell displace w/20 bbls H2O.Rig displace w/594 bbls @ 5952 stks of 11.1 ppg LSND.Bump plug w/4 bbls over calculated. ICP=6 bpm©650 psi&FCP 3 bpm @ 640 psi.Pressure up 500 psi over to 1100 psi&hold for 5 min. Check floats(good)No returns& no reciprocation while cementing. CIP©20:00 hrs Lost 700 bbls mud on 1st stage cement job. 20:30 21:15 0.75 INTRM2 CEMENT CIRC P 13,421.0 13,421.0 PJSM on 2nd stage.Open stage collar w/3480 psi.Attempt to circulate w/1.5 bpm @ 420 psi. 50%returns Lost 15 bbls mud while circulating. 21:15 23:00 1.75 INTRM2 CEMENT CMNT P 13,421.0 13,421.0 Dowell pump 50 bbls 12.0 ppg Mud Push,90.2 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement,drop closing plug.Dowell displace w/20 bbls H2O. Rig displace w/273 bbls @ 2733 stks of 11.1 ppg LSND. ICP=7 bpm @ 550 psi&FCP 3 bpm @ 380 psi.Pressure up 1480 psi&close stage collar,cont.to 2000 psi& hold for 5 min.Check floats (good)50% returns while pumping mud push&cement. 100%returns while displacing. CIP©22:40 hrs Lost 74 bbls on 2nd stage cement job.Lost 1250 bbls total during casing&cementing operations. 23:00 00:00 1.00 INTRM2 CEMENT RURD P 0.0 0.0 L/D Volant tool&L/D landing jt. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ibf/100ft2) (Ibf/100ft2) (Ibf/100ft2) MBT(lb/bbl) (mU3omin) pH (CF) (%) LSND 13,432.0 11.10 43 12.0 18.0 8.0 9.0 9.000 1.3 9.9 10.0 60.0 LSND 13,432.0 11.10 50 13.0 23.0 10.0 13.0 15.000 11.3 9.7 70.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-313 250.0 CD1-01 AES 77 CD5-313 Source Well Page 2/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs CD5-313 ,. Report Number: 32 Cillaps Rig: DOYON 19 Report Date: 7/25/2015 Wellbores Wellbore Name Wellbore APUUWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Casing Strings Csg Des Run Date OD(in) Wt/Len(lb/ft) Grade Set Depth(ftKB) Com INTERMEDIATE 7/25/2015 7 5/8 29.70 L80 13,421.6 13 Centek,26 Bow Spring,&29 Tandem Bow Spring Cement Intermediate Casing Cement -Started @ 7/25/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-313 INTERMEDIATE, 13,421.6ftKB Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Intermediate Casing Cement 12,872.0 13,421.6 3 640.0 Fluid Class Amount(sacks) Vol Pumped.)bbl) Dens(lb/gal) Yield,(fE/sack) Est Top(EKE) Est Btm(ftKB) Intermediate Cement G 290 50.9 15.80 1.16 12,872.0 13,421.0 Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 2 Intermediate Casing Cement 5,301.0 6,336.0 3 270.0 Fluid Class Amount(sacks) - Vol Pumped(bbl) Dens(lb/gal) Yield.(fElsack) Est Top(EKE) Est Btm(ftKB). Intermediate Cement G 436 90.2 15.80 1.16 5,301.0 6,336.0 Page 3/3 Report Printed: 12/1/2015 . Daily Drilling Report (No Cost Security Level: AK Development eat 064 t CD5-313 C€�atocopt illsps Report Number: 33 xf Rig: DOYON 19 Report Date: 7/26/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 31.71 33.0 0.00 13,432.0 13,432.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 48.09 3.41 8/11/2015 Last Casing String INTERMEDIATE, 13,421.6ftKB Ops and Depth @ Morning Report 24hr Forecast M/U 6 3/4"BHA Cont.test BOPE.M/U 6 3/4"BHA&single in hole to stage collar. Drill out stage collar. Last 24hr Summary Set pack off&test.Cut&slip drill line.L/D 5"DP(146 stands).C/O saver sub&service top drive. R/U&test BOPE General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 44°F,Wind N 9 mph,VIS 10 mi,Fog in 52.0 Rig&Camp on high line power. Morning Supervisor Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuel) Drilling Engineer Time Log Time P Start lime End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:45 1.75 INTRM2 CEMENT WWSP P 0.0 0.0 FMC pull wear ring&set pack off.Test pack off to 5000 psi (good).SIMOPS-LID casing tools&equipment.Remove roller on skate. Prep to slip&cut drill line. 01:45 03:15 1.50 INTRM2 CEMENT SLPC P 0.0 0.0 PJSM.Slip&cut 120'drill line. 03:15 04:00 0.75 INTRM2 CEMENT SVRG P 0.0 0.0 Service rig,top drive&draw works. 04:00 18:00 14.00 INTRM2 CEMENT PULD P 0.0 0.0 PJSM.LID 5"DP via mouse hole 146 stands total.(Stripped 2 MPD elements of 5"DP) SIMOPS-@ 14:00 hrs AD LOT, 300 bbl water flush,&82 bbl freeze protect on 10-3/4"X 7-5/8" OA. 18:00 21:00 3.00 INTRM2 CEMENT RURD P 0.0 0.0 C/O saver sub on top drive to 4" XT39,SIMOPS-C/O top rams to 3 1/2"X 6"VBR's 21:00 22:00 1.00 INTRM2 WHDBOP RURD P 0.0 0.0 Install test plug,flood lines,&R/U to test BOPE. 22:00 00:00 2.00 INTRM2 WHDBOP BOPE P 0.0 0.0 Test BOPE w/4"test jt.Annular& HCR kill/choke to 250/2500 psi (good).Choke valves 1 &4-14, man/auto IBOP,4"demco, needle valve,FOSV,&top 3 1/2" x 6"VBR's to 250/3500 psi. (good) Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gal) Vis(s/qt) PV Calc(cP) (Ibf/100115 (Ibf/100ft') (Ibf/100ft') (Ibf/100fF) MBT(lb/bbl) (mU3Omin) pH (°F) (%) LSND 13,432.0 10.10 42 10.0 17.0 7.0 9.0 10.000 2.5 10.5 58.0 LSND 13,432.0 10.10 38 10.0 17.0 8.0 10.0 11.000 2.5 10.4 58.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Diesel 82.0 CD5-313 FP 10 3/4"X 7 5/8"OA Drilling Mud WBM CD5-313 500.0 CD1-01 AES 78,79 CD5-313 Source Well Latest BOP Test Data Date Com 7/15/2015 ROPE Test Test with 5"test joint Test Annular to 250/2 500 nsi for 5 min Test choke valves#1 - 14 and needle valve to 250/3.500. Page 1/2 Report Printed: 12/1/2015 • Daily Drilling Report (No Cos 0 r CD5-313 Security Level: AK Development , illtps Report Number: 33 ConocoPh AW I. Rig: DOYON 19 Report Date: 7/26/2015 Injection Fluid Fluid Source _ From Lease(bbl) Dest Vendor Manifest Number Note Fresh Water 310.0 CD5-313 H2O Flush OA Wellbores Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act Btrn(fIKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Page 2/2 Report Printed: 12/1/2015 • Security Level: AK Development 0:1 Daily Drilling Report (No Costs CD5-313 Conoco 'hilllips Report Number: 34 Atm*. Rig: DOYON 19 Report Date: 7/27/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 32.71 34.0 0.00 13,432.0 13,432.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 48.09 3.41 8/11/2015 Last Casing String INTERMEDIATE, 13,421.6ftKB Ops and Depth @ Morning Report 24hr Forecast Testing Casing Single in hole to top of baffle collar.Drill out shoe track.Displace to 9.8 ppg PowerPro.Drill 20'new hole.FIT.Drill Ahead Last 24hr Summary Cont.test BOPE. M/U 6 3/4"BHA&single in hole w/4"DP to stage collar.Test casing to 1000 psi.Drill out stage collar.Cont.to single in hole w/4"DP to 9,187' General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 47°F,Wind NW 10 mph,VIS 10 mi,Fog in 54.0 Rig&Camp on high line power. Morning supervisor Title Ken Harding Rig Supervisor Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuel) Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 04:00 4.00 INTRM2 WHDBOP BOPE P 0.0 0.0 Cont.to test BOPE-lower 3 1/2" x 6"VBR's,choke valves 1 &2, man choke/kill&HCR choke/kill to 250/3500 psi(good).Test w/4 1/2"test jt-Annular to 250/2500 psi(good)Upper/lower pipe rams&blind rams to 250/3500 psi(good)Super&man choke to 1100 psi(good)Accumulator test, Int 3100 psi/1450 psi after function,33 sec to first 200 psi& 174 sec to full system psi.4 bottles @ 2000 psi.Gas alarms tested.Test waived by AOGCC Matt Herrera 04:00 04:30 0.50 INTRM2 WHDBOP RURD P 0.0 0.0 R/D testing equipment&blow down lines. Install 7.1875"ID wear ring. 04:30 05:15 0.75 INTRM2 CEMENT BHAH P 0.0 0.0 Bring BHA tools&equip to rig floor.C/O elevators f/5"to 4" 05:15 07:30 2.25 INTRM2 CEMENT BHAH P 0.0 375.0 PJSM&M/U 6 3/4"production BHA as per SLB. 07:30 08:30 1.00 INTRM2 CEMENT PULD P 375.0 1,298.0 Single in hole while picking up 4" DP f/375'to 1,298'.Fill pipe every 20 stands 08:30 08:45 0.25 INTRM2 CEMENT RURD P 1,298.0 1,298.0 PJSM-Install back saver slips 08:45 09:15 0.50 INTRM2 CEMENT PULD P 1,298.0 1,510.0 Single in hole while picking up 4" DP f/1,298'to 1,510' 09:15 09:45 0.50 INTRM2 CEMENT DHEQ P 1,510.0 1,510.0 Shallow hole test MWD w/220 gpm @ 950 psi,40 rpm @ 1 k trq (good) 09:45 14:45 5.00 INTRM2 CEMENT PULD P 1,510.0 6,149.0 Single in hole while picking up 4" DP f/1,510'to 6,149'.Fill pipe every 20 stands 14:45 15:30 0.75 INTRM2 CEMENT PRTS P 6,149.0 6,149.0 R/U testing equip.Break circ @ 3 bpm.Pressure test casing to 1000 psi(good).R/D testing equipment. Latest BOP Test Data Date Corn 7/27/2015 I Test BOPF w/4"&4-1/2"test its. (Annular&HCR choke/kill 250/2500 nsi&chart for 5 min-passed)(Choke valves#1 - 14. HCR ch Page 1/3 Report Printed: 12/1/2015 Security Drilling Report (No Cost Level: AK Development 04,, • oil CD5-313 C€moca hillips o Report Number: 34 011.571. Rig: DOYON 19 Report Date: 7/27/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 15:30 17:45 2.25 INTRM2 CEMENT COCF P 6,149.0 6,336.0 Wash in hole f/6,149'to 6,336' w/200 gpm @ 1030 psi,60 rpm @ 5.7 k trq.(Tag TOC @ 6,315' w/5 k) 17:45 19:00 1.25 INTRM2 CEMENT DRLG P 6,336.0 6,339.0 Drill out stage collar f/6,336'to 6,339'w/150 gpm @ 750 psi,40- 70 rpm @ 5-7 k trq,5-12 k WOB PU wt 155 k,SO wt 105 k, ROT wt 120 k 19:00 20:00 1.00 INTRM2 CEMENT REAM P 6,339.0 6,526.0 W&R(/6,339'to 6,526'w/250 gpm @ 1560 psi,60 rpm @ 5.7 k trq. 20:00 22:30 ' 2.50 INTRM2 CEMENT PULD P 6,526.0 8,575.0 Single in hole while picking up 4" DP f/6,526'to 8,575'.Fill pipe every 20 stands (Hole did not take proper displacement f/8,416'to 8,575') 22:30 23:15 0.75 INTRM2 CEMENT CIRC T Fluids Other 8,575.0 8,575.0 F/C(observe significantly aired up mud w/slight ooze down flow line)Circ B/U w/240 gpm @ 1680 psi,60 rpm @ 8.3 k trq.Even mud mud 10.5 ppg in/out&add defoamer.F/C(static) 23:15 00:00 0.75 INTRM2 CEMENT PULD P 8,575.0 9,187.0 Single in hole while picking up 4" DP f/8,575'to 9,187'.Fill pipe every 20 stands Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100f1') (Ibf/100ft') (Ibf/100fF) (Ibf/100ft2) MBT(Ib/bbl) (mU30min) pH ('F) (%) LSND 13,432.0 10.50 37 10.0 15.0 5.0 6.0 8.000 3.8 11.1 70.0 LSND 13,432.0 10.40 39 11.0 14.0 7.0 8.0 9.000 3.8 10.7 59.0 Injection Fluid Fluid Source From Lease(bbl) Gest Vendor Manifest Number Note Drilling Mud WBM CD5-313 250.0 CD1-01 AES 80 CD5-313 Source Well Drill Strings: BHA No.5 - PowerDrive RSS / Bit Run No. <Bit Run?>- 6 3/4in,MDi513,JK5374 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 13,432.0 20,835.0 0.43 10/10/11/11/11 1-2-ER-T-X-0-WT-TD Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 62.34 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 94.84 3 HWDP(3 Jts.) 4 2.563 39 XT 186.18 WEPS PDC Reamer 4.92 2.563 39 XT 191.92 XO-XT39 Box x 3.51 F Pin 5.05 2.250 39 XT 194.43 Steel Float Sub w/NPFV 5 2.250 3 1/2 IF 196.88 1 Non Mag Flex Collar 4 5/8 2.440 3 1/2 IF 227.67 1 Non Mag Flex Collar 4.88 2.250 3 1/2 IF 258.44 NM Stabilizer 4.78 2.250 3 1/2 IF 264.28 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 295.39 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 328.91 Periscope-LWD(Dir&Logging) 4 3/4 2.250 35 NC 353.85 PowerDrive X6 4.88 3.000 35 NC 375.77 Page 2/3 Report Printed: 12/1/2015 • KO Daily Drilling Report (No Costs CD5-313 Security Level: AK Development .�� Report Number: 34 ps Rig: DOYON 19 Report Date: 7/27/2015 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (10005) (rpm) SPP(psi) (10001bf) (10001bf) (1000151) Off Btm Tq Drill Tq 13,432.0 13,432.0 6,315.0 6,339.0 150 12 70 750.0 155 120 105 5.5 7.0 Wellbores Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Page 3/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Costs CD5-313 ccrstos.+of+hilhps. Report Number: 35 Rig: DOYON 19 Report Date: 7/28/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-313 Development 33.71 35.0 276.00 13,432.0 13,708.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 6/24/2015 6/25/2015 51.50 46.68 4.82 8/9/2015 Last Casing String INTERMEDIATE, 13,421.6ftKB Ops and Depth @ Morning Report 24hr Forecast Depth 13,776'(Well Shut In) Dress shakers,Condition mud.RIH&resume drill 6 3/4"production section to+/-20,340' Last 24hr Summary Single in hole w/4"DP to 13,120.Test casing to 3500 psi. Drill out shoe track to shoe. Displace to Power Pro. Drill rat hole&20'new formation to 13,452'. FIT to 12.5 ppg. Drill ahead f/13,452'to 13,708'. Decision made to pull to shoe due to shakers blinded off,mud properties out of speck,&shakers screended to tight. Pump OOH f/13,708'to 13,393' General Remarks Weather Head Count No Incidents,No Accidents,&No Spills 43°F,Wind N 7 mph,VIS 10 mi, Fog in 58.0 Rig&Camp on high line power. Morning Supervisor Title Donnie Lutrick Fld Drlg Supv Adam Dorr Rig Supervisor Joseph Engel Rig Engineer JG Samuell Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 04:15 4.25 INTRM2 CEMENT PULD P 9,187.0 13,120.0 Single in hole while picking up 4" DP f/9,187'to 13,120'.Fill pipe every 20 stands 04:15 05:30 1.25 INTRM2 CEMENT PRTS P 13,120.0 13,120.0 R/U testing equipment.Break circ &test casing to 3500 psi&chart for 30 min(good).R/D testing equipment.SIMOPS-R/U to drill w/90'mouse hole 05:30 06:00 0.50 INTRM2 CEMENT SEQP P 13,120.0 13,120.0 Calibrate block height w/MWD 06:00 07:30 1.50 INTRM2 CEMENT COCF P 13,120.0 13,290.0 Wash in hole f/13,120'to 13,290' w/200-220 gpm @ 1690-2140 psi,60 rpm©13 k trq.(Tag TOC @ 13,285'w/5 k) 07:30 12:00 4.50 INTRM2 CEMENT DRLG P 13,290.0 13,421.0 Drill out baffle collar,float collar, &shoe f/13,290"to 13,421' w/150-220gpm @ 1180-1630 psi,40-70 rpm @ 13-17 k trq,5 -12 k WOB PU wt 260 k,SO wt 130 k,ROT wt 175 k. Displace to 9.8 ppg Power Pro on the fly.Pump 35.5 bbls high vis spacer&chase with new 9.8 ppg Power Pro WBM. 12:00 12:30 0.50 INTRM2 CEMENT DISP P 13,421.0 13,421.0 Finish displacing well to 9.8 ppg Power Pro w/220 gpm @ 1630 psi,70 rpm @ 16.1 k trq 12:30 13:00 0.50 INTRM2 CEMENT DRLG P 13,421.0 13,432.0 Drill rat hole f/13,421'to 13,432' w/220 gpm @ 1630 psi,70 rpm @16.1ktrq 13:00 13:30 0.50 INTRM2 CEMENT DDRL P 13,432.0 13,452.0 Drill 20'new formation f/13,432' to 13,452'MD/TVD 7,348' ADT.29 hrs.250 gpm @ 2080 psi,80 rpm @ 17.3 k trq 13:30 14:30 1.00 INTRM2 CEMENT CIRC P 13,452.0 13,393.0 Circ B/U w/250 gpm @ 2100 psi, 80 rpm @ 17 k trq.POOH to inside casing f/13,452'to 13,393' Latest BOP Test Data Date Com 7/27/2015 Test BOPF w/4"&4-1/2"test its. (Annular& HCR choke/kill 250/2500 nsi&chart for 5 min-nassedl (Choke valves#1 - 14. HCR ch... Page 1/3 Report Printed: 12/1/2015 i. IIIDaily Level: AK Development b Daily Drilling Report (No Costs CD5-313 Conn hiWps Report Number: 35 /.kasha Rig: DOYON 19 Report Date: 7/28/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 14:30 15:00 0.50 INTRM2 CEMENT OWFF P 13,393.0 13,393.0 F/C(static) 15:00 15:30 0.50 INTRM2 CEMENT FIT P 13,393.0 13,393.0 R/U testing equipment.FIT to 12.5 ppg @ 1030 psi. R/D testing 15:30 17:15 1.75 PROD1 DRILL MPDA P 13,393.0 13,452.0 Remove trip nipple&install RCD element.Establish circulation through chokes while washing in hole f/13,303'to 13,452'w/250 gpm @2100 psi,80 rpm @17k trq. 17:15 22:30 5.25 PROD1 DRILL DDRL P 13,452.0 13,708.0 Drill ahead 6 3/4"production hole f/13,452'to 13,708'MD/7,347' TVD,ADT 3.72 hrs,ECD 10.37 ppg,250 gpm, 1080 psi,5-8 wob, PU wt 270 k,SO wt 124 k, ROT wt 165 k,Drill trq 15.8 k ft/lbs,Off bottom trq 14.7 k ft/lbs 22:30 23:00 0.50 PROD1 DRILL CIRC T Fluids Other 13,708.0 13,708.0 Shakers blinded off due to greasing&would not keep fluid on shakers,Shakers screened to tight.Mud properties out of spec with low end rheology.Reduced flow rate to 3 bpm&attempt to clean shaker screens with no success.Decision made to pump out of hole to shoe&re-dress shakers&condition mud. 23:00 00:00 1.00 PROD1 DRILL PMPO T Fluids Other 13,708.0 13,393.0 Pump OOH f/13,708'to 13,393' w/3 bpm @ 680-580 psi. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100fF) (Ibf/100ft') (Ibf/100ft2) (Ibf/100ft9 MBT(Ib/bbl) (mU3Omin) pH (°F) 1%) PowerPro 13,600.0 9.80 37 6.0 11.0 6.0 8.0 9.000 1.3 9.1 83.0 PowerPro 13,432.0 9.80 37 8.0 11.0 7.0 8.0 9.000 9.7 80.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-313 775.0 CD1-01 AES 81,82,83 CD5-313 Source Well Drill Strings: BHA No.5 - PowerDrive RSS / Bit Run No. <Bit Run?>- 6 3/4in,MDi513,JK5374 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(ink) Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 13,432.0 20,835.0 0.43 10/10/11/11/11 1-2-ER-T-X-0-WT-TD Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 2 HWDP(2 Jts.) 4 2.563 39 XT 62.34 1 Drilling Jars-Hydraulic 4 3/4 2.250 39 XT 94.84 3 HWDP(3 Jts.) 4 2.563 39 XT 186.18 WEPS PDC Reamer 4.92 2.563 39 XT 191.92 XO-XT39 Box x 3.5IF Pin 5.05 2.250 39 XT 194.43 Steel Float Sub w/NPFV 5 2.250 3 1/2 IF 196.88 1 Non Mag Flex Collar 4 5/8 2.440 3 1/2 IF 227.67 1 Non Mag Flex Collar 4.88 2.250 3 1/2 IF 258.44 NM Stabilizer 4.78 2.250 3 1/2 IF 264.28 1 Non Mag Flex Collar 4 3/4 2.250 3 1/2 IF 295.39 Impulse-MWD(Directional) 4 3/4 2.250 3 1/2 IF 328.91 Periscope-LWD(Dir&Logging) 4 3/4 2.250 35 NC 353.85 Page 2/3 Report Printed: 12/1/2015 6. 1% • • Daily Drilling Report (No Costs) 0 a CD5-313 Security Level: AK Development Report Number: 35 ConocoPhdhps Rig: DOYON 19 Report Date: 7/28/2015 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) PowerDrive X6 4.88 3.000 35 NC 375.77 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (10001bt) (rpm) SPP(psi) (10001bf (10001bt) (1000Ibt) Off Btm Tq Drill Tq 6,315.0 6,339.0 150 12 70 750.0 155 120 105 5.5 7.0 13,285.0 13,432.0 150 12 70 2,080.0 260 175 130 13.0 17.0 13,432.0 13,452.0 20.00 0.29 250 10 70 2,080.0 260 175 130 13.0 17.0 13,452.0 13,708.0 276.00 4.30 250 8 100 1,840.0 270 165 124 14.7 15.8 Welibores Wellbore Name Wellbore API/UWI CD5-313 501032071400 Section Des Size(in) Act Top(ftKB) Act atm(ftKB) Start Date End Date CONDI 42 36.5 115.5 3/12/2015 3/12/2015 SURFAC 131/2 115.5 2,270.0 6/25/2015 7/2/2015 INTRM2 9 7/8 2,270.0 13,432.0 7/16/2015 7/28/2015 PROD1 6 3/4 13,432.0 20,835.0 7/28/2015 8/11/2015 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 13,460.56 88.92 162.38 7,347.94 9,299.50 -8,290.63 6,085.63 4.62 13,524.61 90.25 165.08 7,348.40 9,363.27 -8,352.10 6,103.57 4.70 13,619.55 90.69 168.64 7,347.62 9,458.13 -8,444.55 6,125.15 3.78 Leak Off and Formation Integrity Tests Leak Dens Fluid LO Eq Fluid Den off? 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Y65 oe U II Tr M M N N �, m MIflSS d E E 6 2 w 0 • • CD5-09 Surface Casing Well: CD5-09 10-3/4"45.5#L-80 BTC-M& Hyd 563 Surface Casing Date: ConocoPhillips it - CRig: Doyon 19 Alaska.Enc. Depth Jt Number Joints INA! Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring FMC 10-3/4" Casing Hanger .17 36.83 10-3/4", 45.5#, L-80, HYD563 Casing Pup, pin x pin 2.21 37.00 Pup 10-3/4", 45.5#, L-80, HYD563 Casing 29.24 39.21 Jts 4 to 54 51 Jts 10-3/4", 45.5#, L-80, HYD563 Casing 2173.06 68.45 XO 10-3/4", 45.5#, L-80, HYD563 Casing Box x 10-3/4" BTC-M Pin 42.60 2241.51 Jts 3 to 3 1 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 40.85 2284.11 10-3/4" HES Float Collar 1.21 2324.96 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTC-M Casing 80.32 2326.17 10-3/4" HES Composite Shoe 2.70 2406.49 2409.19 2409.19 2409.19 2409.19 10 3/4" Shoe at 2,409'MD/2,168' TVD 2409.19 13 1/2" TD at 2,422' MD /2,176' TVD 13' rathole 2409.19 2409.19 2409.19 2409.19 2409.19 2409.19 2409.19 2409.19 1 Centek 10' up from shoe w/stop ring above on Jt#1 2409.19 1 Centek 30' up from pin w/stop ring above and below on Jt#2 2409.19 1 Centek 20' up from pin w/stop ring above on Jt#3 2409.19 1 Centek every joint from #4 to#54 Floating 2409.19 2409.19 No centralizer on pup jt 2409.19 Total Centralizers = 55 Centeks, 2409.19 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312TUR 2409.19 2409.19 2409.19 2409.19 2409.19 Remarks: Use Run&Seal pipe dope on BTC-M, Seal Guard ECF on HYD 563 Up Wt 145 K Avg MU Tq with Volant-7.7 k ft/lbs trq for BTC-M & 16.2 k ft/lbs trq for Hyd 563 Dn Wt 125 K Jts Bakerlocked to pin end of#4 Block Wt 60 K Driffted with 9.885"drift Rig Supervisors:Rick Bjorhus/Dan Lowe ii • • Cement Detail Report 0a CD5-09 Conocci'hilips Aksska String: Surface Job: DRILLING ORIGINAL, 11/20/2015 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface 11/23/2015 08:30 11/23/2015 11:00 CD5-09 Comment PJSM. Surface cement job: Dowell pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 71.3 bbls 10.5 ppg Mud Push II, Drop bottom plug, Dowell pump 9 bbls of 11.0 ppg scavenger slurry, 372.2 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm,250-440 psi. Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 3.3-4.4 bpm/580-170 psi. Drop top plug. Dowell pump 10 bbls H2O. Rig displace with 212 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 890 psi,decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min. Check floats-good. Full returns throughout 218 bbls good cement back to surface. Reciprocated pipe with 10'stroke until MudPush exited shoe.Stopped reciprocating due to excess drag and hole appearing to get sticky.CIP at 11:06 hrs, 11/23/15. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface 36.7 2,409.0 Yes 218.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 2 6 250.0 500.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,304.0 Drill Bit Comment Lead= 11.0 ppg DeepCrete,Tail= 15.8 ppg"G" Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Scavenger Scavenger Slurry 36.7 36.7 27 DeepCRETE 9.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1 (psi) 1.91 6.76 0.00 11.00 189.0 5.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement Lead Slurry 36.7 1,945.0 1,094 DeepCRETE 372.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1 (psi) 1.91 6.76 0.00 11.00 189.0 5.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement Tail Slurry 1,945.0 2,409.0 279 Class G 58.2 • Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.14 0.00 15.80 3.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/1/2015 Security Level: AK Development 0114111/ Daily Drilling Report (No Costs 014, CD5-09 oct�lllaps Report Number: 4 Almks Ccxl Rig: DOYON 19 Report Date: 11/23/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-09 Development 2.95 4.0 0.00 2,422.0 2,422.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 11/20/2015 11/21/2015 37.00 34.95 2.04 12/25/2015 Last Casing String Surface,2,409.2ftKB Ops and Depth @ Morning Report 24hr Forecast NU MPD equipment Open OA and monitor. LD annular, NU BOPE/MPD.RU and test BOPs,PU BHA#2 and RIH. Last 24hr Summary Finish running 10-3/4"Surface csg to 2,409'. C&C mud for cementing, RU cement equip,pump and displace Lead and Tail cement slurries,bump plug and check. Close bag preventer/annulus and monitor pressure while picking up 5"DS-50 DP. General Remarks Weather Head Count No AIS.Rig&Camp on high line power. -1°F/WC-5°F,E 23,G32 mph,VIS 4 mi, 53.0 Cloudy Supervisor Title Rick Bjorhus Rig Supervisor Dan Lowe Rig Supervisor Joseph Engel Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 04:30 4.50 SURFAC CASING PUTB P 886.0 2,369.0 Continue running 10-3/4",45.5 lb/ft,L-80, H563,R3 casing to 2,369'. S0=125K(pumps off). 04:30 05:15 0.75 SURFAC CASING HOSO P 2,369.0 2,409.0 MU casing hanger and landing joint. Establish circulation with 2 bpm and 170 psi. Land casing on hanger at 2,409'md. PU= 145K,SO=125K lb. 05:15 07:45 2.50 SURFAC CEMENT CIRC P 2,409.0 2,409.0 Circ&cond mud for cement job Stage flow rate from 0.5-8 bpm, 40-180 psi,reciprocate pipe 10'. (SIMOPs-RD casing tools and equipment.RD 4'bail extensions, 10.75"elevators for TD and LD. Clean&clear floor.PU=140K, S0=135K lb(pumps on). 07:45 08:30 0.75 SURFAC CEMENT RURD P 2,409.0 2,409.0 BD Top drive and RU cement lines to cement swivel. Fill lines with 4.5 bpm,200 psi. Latest BOP Test Data Date I Corn Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Cos CD5-09 = ilbps Report Number: 4 ConocciPh Anka Rig: DOYON 19 Report Date: 11/23/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 08:30 11:00 2.50 SURFAC CEMENT CMNT P 2,409.0 2,409.0 PJSM. Surface cement job: Dowell pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 71.3 bbls 10.5 ppg Mud Push II,Drop bottom plug, Dowell pump 9 bbls of 11.0 ppg scavenger slurry,372.2 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm,250-440 psi.Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 3.3-4.4 bpm/580-170 psi. Drop top plug. Dowell pump 10 bbls H2O. Rig displace with 212 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 890 psi,decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min. Check floats-good.Full returns throughout 218 bbls good cement back to surface.Reciprocated pipe with 10'stroke until MudPush exited shoe.Stopped reciprocating due to excess drag and hole appearing to get sticky. CIP at 11:06 hrs, 11/23/15. 11:00 12:00 1.00 SURFAC CEMENT RURD P 0.0 0.0 Flush surface riser and Annular with black water. Function annular 3X,close and monitor annulus pressure.Check pressure every 10 min for one hour and every 30 min there after. Pressure=11 psi when SI. 12:00 13:30 1.50 SURFAC CEMENT RURD P 0.0 0.0 BD and RD cement lines.RD Volant CRT,power tongs, elevators and LD.Clear and clean rig floor. Monitor pressure under annular. 13:30 16:00 2.50 SURFAC CEMENT WOC P 0.0 0.0 Continue to WOC.Perform Top Drive inspection.SIMOPs- continue to clear and clean the rig floor. 16:00 23:15 7.25 SURFAC CEMENT PULD P 0.0 0.0 PJSM. PU 5"DS50 Hi-Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC. 23:15 23:45 0.50 SURFAC CEMENT OWFF P 0.0 0.0 PU/MU stack washer. Check pressure under annular(initial= 11 psi,final= 15 psi).Open annulus valve, intermittent droplets after 10 minutes.Open annular preventer and drain stack. 23:45 00:00 0.25 SURFAC CEMENT RURD P 0.0 0.0 Lay down 10-3/4"landing joint. Page 2/3 Report Printed: 12/1/2015 Security Level: AK Development \ 1 , Daily Drilling Report (No Costs r.\- -:11101,W5,6': CD5-09 , Report Number: 4 ConocoPttilbps ;; Rig: DOYON 19 Report Date: 11/23/2015 Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(EKE) Dens(Ib/gal) Vis.(s/gt) PV Calc(cP) (Ibf/100fF) (Ibf/100ft') (Ibt/100ft') (lbf/100ftE) MET(Ib/bbl) (m1'/30min) pH (°F) (.°A) DRILPLEX 2,422.0 10.00 DRILPLEX 2,422.0 10.00 17.0 8.0 3.0 14.0 20.000 15.0 10.7 60.0 DRILPLEX 10.00 10.0 3.0 3.0 3.0 4.000 15.0 10.1 54.0 Injection Fluid Fluid - Source From Lease(bbl) Dest. Vendor Manifest Number Note Drilling Mud WBM 280.0 CD1-01 AES 35589 CD5-09 Source Well Drilling Mud WBM 280.0 CD1-01 AES 35591 CD5-09 Source Well Drilling Mud WBM 275.0 CD1-01 AES 35592 CD5-09 Source Well Drilling Mud WBM 250.0 CD1-01 AES 35590 CD5-09 Source Well Drilling Mud WBM 250.0 CD1-01 AES 35593 CD5-09 Source Well Drilling Mud WBM 250.0 CD1-01 AES 35594 CD5-09 Source Well Wellbores Wellbore Name Wellbore API/UWI CD5-09 501032072300 Section Des,'. Size(in) Act Top.(ftKB) Act Btm(ftKB) _ Start Date End Date PROD1 6 1/2 CONDI 20 0.0 115.0 3/24/2015 3/24/2015 SURFAC 13 1/2 115.0 2,422.0 11/22/2015 11/25/2015 I NTRM 1 11 2,422.0 11/25/2015 Cement Surface -Started @ 11/23/2015 Type Wellbore Cemented String Cement Evaluation Results Casing CD5-09 Surface,2,409.2ftKB Good Stg# Description Top Depth(ftKB) Bottom Depth(ftKB) Q Pump Final... P Pump Final(psi) 1 Surface 36.7 2,409.0 2 250.0 Fluid Class Amount(sacks) Vol Pumped(bbl) Dens(Ib/gal). Yield(fF/sack) Est Top(EKE) Est.Btm(ftKB) Scavenger DeepCRETE 27 9.0 11.00 1.91 36.7 36.7 Lead Cement DeepCRETE 1,094 372.2 11.00 1.91 36.7 1,945.0 Tail Cement Class G 279 58.2 15.80 1.17 1,945.0 2,409.0 Page 3/3 Report Printed: 12/1/2015 •i Daily Drilling Report (No Costs Security Level: AK Development 0 CD5-09 ConocoPh➢lhps Report Number: 5 "ask' Report Date: 11/24/2015 Rig: DOYON 19 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-09 Development 3.95 5.0 0.00 2,422.0 2,422.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 11/20/2015 11/21/2015 37.00 34.95 2.04 12/25/2015 Last Casing String Surface,2,409.2ftKB Ops and Depth @ Morning Report 24hr Forecast Fumction test w/MPD&new software M/U BHA#2, RIH to 2,325'.Test casing to 3500 psi.MPD fingerprint.Drill out to 2,442'.Displace to 9.6 ppg LSND.FIT to 18.0 ppg.Open reamer&drill ahead 9 7/8"X 11"intermediate hole section. Last 24hr Summary N/D riser&annular. N/U well head&test. N/U BOPE. N/U MPD flow box&valves. Install trip nipple.Test BOPE. R/U MPD hoses&clamps.Test MPD lines& choke. Install wear ring.M/U BHA#2. General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 7°F/WC-10°F, E 14 mph,VIS 10 mi,Clear 56.0 Tested gas alarms Supervisor Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 01:15 1.25 SURFAC WHDBOP WWWH P 0.0 0.0 M/U stack washer&flush stack. B/D top drive&L/D same. 01:15 05:00 3.75 SURFAC WHDBOP NUND P 0.0 0.0 R/D drain lines. B/D hole fill& bleeder lines.N/D flow line, surface riser.N/D annular preventer&speed lock adaptor. 05:00 05:30 0.50 SURFAC WHDBOP NUND P 0.0 0.0 N/U well head&test to 1000 psi for 10 min(good) 05:30 08:00 2.50 SURFAC WHDBOP NUND P 0.0 0.0 N/U BOPE,choke lines& annulus valves. 08:00 12:00 4.00 SURFAC WHDBOP MPDA P 0.0 0.0 N/U RCD clamp,flow box,flow lines&bleeder valves.N/U MPD lines&orbit valve.Install trip nipple.SIMOPS-Charge koomy unit&install 90'mouse hole. 12:00 13:00 1.00 SURFAC WHDBOP RURD P 0.0 0.0 P/U 5"test jt&set test plug.R/U testing equipment.Fill stack& lines w/H20.SIMOPS-Tested gas alarms. Latest BOP Test Data Date Com 11/24/2015 ROPE Test Test with 5"test mint. Test Annular to 250/2 500 nsi fnr 5 min Test choke valves#1 - 14 and needle valve to 250/3.500 Page 1/3 Report Printed: 12/1/2015 Security Level: AK Development Daily Drilling Report (No Costs CD5-09 it Con$34 •lilltps Report Number: 5 Araks Rig: DOYON 19 Report Date: 11/24/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 13:00 17:00 4.00 SURFAC WHDBOP BOPE P 0.0 0.0 BOPE Test:Test with 5"test joint,Test Annular to 250/2,500 psi for 5 min,Test choke valves #1 -14 and needle valve to 250/3,500 psi for 5 min.HCR Choke and Kill,4"Demco,5" FOSV,dart&needle valves,auto &manual IBOP,HCR choke& kill,3 1/2"X 6"upper&lower VBR's,&blind rams to 250/3500 psi for 5 min.-good.Koomey test; IP=3,100 psi,manifold press after close=1,550 psi,200 psi recovery 36 sec,full recovery 210 sec, N2-4 bottle average= 1959 psi.Draw down on man& super choke to 1,100 psi. - Test witnessed by Brian Bixby of the AOGCC. 17:00 21:15 4.25 SURFAC WHDBOP MPDA P 0.0 0.0 Finish R/U MPD equipment.R/U catch can&2"MPD valves. Remove trip nipple&install MPD test plug.Test MPD equipment to 200/1200 psi&chart.Stab MPD bearing on stand of 5"DP&rack back in derrick. Install MPD trip nipple. 21:15 22:15 1.00 SURFAC WHDBOP RURD P 0.0 0.0 M/U test jt&pull test plug. Install 10"ID wear ring.Clean&clear floor. 22:15 22:30 0.25 SURFAC CEMENT SFTY P 0.0 0.0 PJSM on BHA 22:30 00:00 1.50 SURFAC CEMENT BHAH P 0.0 108.0 M/U BHA#2 as per SLB to 108' Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(EKE) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') (Ibf/100ft') MBT(Ib/bbl) (mL/30min) pH ('F) (%) DRILPLEX 2,422.0 10.00 32.0 40.0 34.0 49.0 72.000 15.0 10.6 55.0 DRILPLEX 2,422.0 10.00 33.0 39.0 33.0 51.0 74.000 15.0 10.1 59.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Pit Rinsate 250.0 CD1-01 AES 35595 CD5-09 Source Well Drill Strings: BHA No.2 - Rotary Steerable / Bit Run No. 2 - 9 7/8in,MSi516,JK1987 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000lbf) 2,422.0 11,264.0 0.98 16/16/16/16/16 1-2-CT-C-X-I-WT-DSF 205 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 93 DP DS 50 5 4.276 4 1/2 IF 2,903.84 243 DP NC-50 5 4.276 4 1/2 IF 10,535.69 9 HWDP x9 5 3.000 4 1/2 IF 10,810.56 1 6 1/4"Hydraulic Combo Jars 6 1/4 2.250 4 1/2 IF 10,840.57 9 HWDP x9 5 3.000 4 1/2 IF 11,116.31 Steel Float Sub(NPFV) 7.12 2.810 4 1/2 IF 11,119.54 NM Stabilizer 6.81 2.810 4 1/2 IF 11,126.75 1 7 1/4"NMDC 7.18 2.875 4 1/2 IF 11,157.50 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 11,169.40 Steel Float Sub(NPFV) 7 2.810 4 1/2 IF 11,172.63 Page 2/3 Report Printed: 12/1/2015 „,.4 Security Level: AK Development ',, d Daily Drilling Report (No Costs r`r. r k CD5-09 i � Report Number: 5 ConocoPhiY,isAa Rig: DOYON 19 Report Date: 11/24/2015 Drill String Components Jts Item Des OD(in) ID(in) Top ConnSz(in) _ Top Thread Cum Len(ft) NM Stabilizer 6.8 2.875 4 1/2 IF 11,179.80 7 1/4”NMPC 7 1/4 2.875 4 1/2 IF 11,189.90 6 3/4"TeleScope MWD 7 3.880 4 1/2 IF 11,217.81 6 3/4"PeriScope 6 3/4 2.810 5 1/2 FH 11,239.74 6 3/4"Xceed 9 3/4"Stabilizers 6 3/4 5.160 5 1/2 FH 11,264.77 Drilling Parameters Flow.Rate End Depth Sliding (gpm) WOB RPM PU Str Wt. Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (10001bf) (rpm) SPP(psi) (10001bf)r (10001bf) (10001bf) Off Btm Tq Drill Tq 2,422.0 2,422.0 Wellbores Wellbore Name Wellbore API/UWI CD5-09 501032072300 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start.Date End Date., PROD1 6 1/2 CONDI 20 0.0 115.0 3/24/2015 3/24/2015 SURFAC 13 1/2 115.0 2,422.0 11/22/2015 11/25/2015 I NTRM 1 11 2,422.0 11/25/2015 Page 3/3 Report Printed: 12/1/2015 z • Security Level: AK Development r • Daily Drilling Report (No Costs 00rpt CD5-09 - iffips Report Number: 6 ConocoPh Aradza Rig: DOYON 19 Report Date: 11/25/2015 Wellbore Well Type DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) CD5-09 Development 4.95 6.0 660.00 2,422.0 3,082.0 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 11/20/2015 11/21/2015 37.00 32.78 4.22 12/23/2015 Last Casing String Surface,2,409.2ftKB Ops and Depth @ Morning Report 24hr Forecast Drill Ahead 3,850' Drill ahead 9 7/8"X 11"Intermediate to+/-13,200' Last 24hr Summary Cont.to M/U BHA#2.RIH to 2,228'.Shallow hole test&circ B/U.Test casing to 3500 psi. Install MPD bearing.Conduct ramp up&ramp down with new MPD software. Drill out&drill 20'new formation to 2,454'.Circ B/U. FIT to 18.0 ppg. Drill ahead f/2,454'to 2,550'. Drop ball&open reamer. Drill ahead f/2,550'to 3,082' General Remarks Weather Head Count No AIS.Rig&Camp on high line power. 23°F/WC 10°F,W 15 mph,VIS 10 mi,Blowing 57.0 Snow Supervisor Title Rick Bjorhus Rig Supervisor Adam Dorr Rig Supervisor Tom Polasek Rig Engineer Will Earhart Drilling Engineer Time Log TmeP Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 00:00 00:45 0.75 SURFAC CEMENT BHAH P 108.0 149.0 Cont.to M/U BHA#2 as per SLB to 149' 00:45 02:30 1.75 SURFAC CEMENT TRIP P 149.0 2,228.0 RIH f/149'to 2,228' 02:30 03:00 0.50 SURFAC CEMENT DHEQ P 2,228.0 2,228.0 Shallow hole test MWD&cvirc B/U w/675-575 gpm @ 2140- 1600 psi,30 rpm @ 4.5 k trq 03:00 04:30 1.50 SURFAC CEMENT PRTS P 2,228.0 2,228.0 R/U testing equip&test casing to 3500 psi&chart for 30 min (good).R/D testing equip&B/D lines 04:30 08:00 3.50 SURFAC CEMENT MPDA P 2,228.0 2,228.0 Pull trip nipple&install MPD bearing.Conduct ramp up& ramp down with new software as per MPD advisor.B/D lines. Remove MPD bearing&install trip nipple. 08:00 10:30 2.50 SURFAC CEMENT COCF P 2,228.0 2,324.0 W&R f/2,228'to top of float collar @ 2,324'w/550 gpm @ 1420 psi, 30-5o rpm @ 5 k trq.(Tag TOC @ 2,304') 10:30 12:45 2.25 SURFAC CEMENT DRLG P 2,324.0 2,442.0 Drill out shoe track&rat hole f/2,324'to 2,442'w/550 gpm @ 1060 psi,60 rpm @ 5 k trq. Displace to 9.6 ppg LSND on the fly 12:45 13:00 0.25 SURFAC CEMENT TRIP P 2,442.0 2,237.0 B/D top drive&POOH f/2,442'to 2,237' 13:00 14:00 1.00 SURFAC CEMENT OWFF P 2,237.0 2,237.0 F/C(static) 14:00 14:45 0.75 SURFAC CEMENT TRIP P 2,237.0 2,442.0 RIH f/2,237'to 2,442' 14:45 15:00 0.25 SURFAC CEMENT DDRL P 2,442.0 2,454.0 Drill ahead f/2,442'to 2,454' 15:00 15:30 0.50 SURFAC CEMENT CIRC P 2,454.0 2,454.0 Circ B/U w/550 gpm @ 1060 psi, 60 rpm @ 5 k trq.SIMOPS- PJSM on FIT 15:30 16:00 0.50 SURFAC CEMENT TRIP P 2,454.0 2,232.0 POOH f/2,454'to 2,232' 16:00 16:45 0.75 SURFAC CEMENT FIT P 2,232.0 2,232.0 R/U testing equip&FIT to 18.0 PPO 16:45 17:00 0.25 INTRM1 DRILL TRIP P 2,232.0 2,454.0 RIH f/2,232'to 2,454' Latest BOP Test Data Date Corn 11/24/2015 I ROPF Test Test with 5"test joint Test Annular to 250/2-500 nsi for 5 min. Test choke valves#1 -14 and needle valve to 250/3 500--. Page 1/3 Report Printed: 12/1/2015 • Security Level: AK Development of Daily Drilling Report (No Cost CD5-09 �Cc tocoPhillips" Report Number: 6 mr k Rig: DOYON 19 Report Date: 11/25/2015 Time Log Time P Start Time End Time Dur(hr) Phase Op Code Activity Code -T-X Trbl Code Trbl Class Start Depth(ftKB) End Depth(ftKB) Operation 17:00 19:15 2.25 INTRM1 DRILL DDRL P 2,454.0 2,550.0 Drill ahead f/2,454'to 2,550' w/750 gpm @ 1840 psi,60 rpm @ 5 k trq.SIMOPS-PJSM on opening reamer. 19:15 20:00 0.75 INTRM1 DRILL CIRC P 2,550.0 2,550.0 Drop 1 1/4"activation ball& pump down w/75 gpm @ 80 psi. Reamer shear @ 1350 psi& open reamer @ 2,526'(11"hole @ 2,424') Reamer closed:750 gpm, 1840 psi,4140 trpm Reamer open:750 gpm, 1420 psi,3515 trpm. 20:00 00:00 4.00 INTRM1 DRILL DDRL P 2,550.0 3,082.0 Drill ahead f/2,550'to 3.082'MD 2,547'TVD,ADT 4.35,ECD 10.66 ppg,775 gpm, 1650 psi, PU wt 123 k,SO wt 112 k,ROT wt 117 k,Trq 3.1/5.6 k ft lbs Mud Check Data YP Calc Gel(10s) Gel(tom) Gel(30m) HTHP Filtrate Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(s/qt) PV Calc(cP) (Ibf/1001V) (Ibf/100fF) (Ibf/100fF) (Ibf/100/F) MBT(Ib/bbl) (mLl3omin) pH (°F) (%) LSND 2,618.0 9.60 45 10.0 28.0 11.0 13.0 13.000 2.5 10.3 76.0 LSND 2,454.0 9.60 45 9.0 22.0 6.0 8.0 9.000 2.0 10.5 62.0 Injection Fluid Fluid Source From Lease(bbl) Dest Vendor Manifest Number Note Drilling Mud WBM CD5-09 275.0 CD1-01 AES 35597 CD5-09 Source Well Drilling Mud WBM CD5-09 250.0 CD1-01 AES 35598 CD5-09 Source Well Drilling Mud WBM CD5-09 100.0 CD1-01 AES 35596 CD5-09 Source Well Drill Strings: BHA No.2 - Rotary Steerable / Bit Run No. 2 - 9 7/8in,MSi516,JK1987 Depth In(ftKB) Depth Out(ftKB) TFA(incl Noz)(in') Nozzles(1/32") IADC Bit Dull String Wt(1000Ibf) 2,422.0 11,264.0 0.98 16/16/16/16/16 1-2-CT-C-X-I-WT-DSF 205 Drill String Components Jts Item Des OD(in) ID(in) Top Conn Sz(in) Top Thread Cum Len(ft) 93 DP DS 50 5 4.276 4 1/2 IF 2,903.84 243 DP NC-50 5 4.276 4 1/2 IF 10,535.69 9 HWDP x9 5 3.000 4 1/2 IF 10,810.56 1 6 1/4"Hydraulic Combo Jars 6 1/4 2.250 4 1/2 IF 10,840.57 9 HWDP x9 5 3.000 4 1/2 IF 11,116.31 Steel Float Sub(NPFV) 7.12 2.810 4 1/2 IF 11,119.54 NM Stabilizer 6.81 2.810 4 1/2 IF 11,126.75 1 7 1/4"NMDC 7.18 2.875 4 1/2 IF 11,157.50 11"Rhino Reamer(NPFV) 7 1/4 3.000 4 1/2 IF 11,169.40 Steel Float Sub(NPFV) 7 2.810 4 1/2 IF 11,172.63 NM Stabilizer 6.8 2.875 4 1/2 IF 11,179.80 7 1/4"NMPC 7 1/4 2.875 4 1/2 IF 11,189.90 6 3/4"TeleScope MWD 7 3.880 4 1/2 IF 11,217.81 6 3/4"PeriScope 6 3/4 2.810 5 1/2 FH 11,239.74 6 3/4"Xceed 9 3/4"Stabilizers 6 3/4 5.160 5 1/2 FH 11,264.77 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOE RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (1000lbf) (rpm) SPP(psi) (1000lbf) (10001bf) (10001bf) Off Btm Tq Drill Tq 2,422.0 2,422.0 Page 2/3 Report Printed: 12/1/2015 • Security Level: AK Development Daily Drilling Report (No Costs kali ' CD5-09 iEbps - Report Number: 6 ConocoPhRig: DOYON 19 Report Date: 11/25/2015 Drilling Parameters Flow Rate End Depth Sliding (gpm) WOB RPM PU Str Wt Drill Str Wt SO Str Wt Start(ftKB) (ftKB) Cum Depth(ft) Cum Drill Time(hr) Time(hr) (gpm) (1000Ibf) (rpm) SPP(psi) (1000Ibf) (1000Ibf). (1000lbf) Off Btm Tq Drill Tq 2,422.0 2,422.0 450 10 50 860.0 135 123 112 4.0 5.5 2,422.0 3,082.0 660.00 4.35 775 12 140 1,650.0 123 117 112 3.1 5.6 Wellbores Wellbore Name Wellbore API/UWI CD5-09 501032072300 Section Des Size(in), Act Top(ftKB) Act.Btm(ftKB) Start Date End Date PROD1 6 1/2 CONDI 20 0.0 115.0 3/24/2015 3/24/2015 SURFAC 13 1/2 115.0 2,422.0 11/22/2015 11/25/2015 INTRM1 11 2,422.0 11/25/2015 Survey Data MD(ftKB) Incl(o).. Azm(') TVD(ftKB) VS(ft) NS(ft) : EW(ft) DLS('/100ft) 2,443.92 46.34 0.52 2,193.52 792.47 814.92 -146.20 0.78 2,456.69 46.74 1.20 2,202.30 800.67 824.19 -146.06 4.98 2,488.32 47.80 0.81 2,223.76 821.18 847.42 -145.66 3.47 2,551.10 49.99 359.58 2,265.03 863.26 894.72 -145.51 3.79 2,643.46 53.32 358.26 2,322.33 928.41 967.13 -146.89 3.78 2,737.16 57.51 357.61 2,375.50 998.34 1,044.20 -149.68 4.51 2,831.88 60.66 358.06 2,424.16 1,072.08 1,125.40 -152.74 3.35 2,925.98 60.52 0.91 2,470.38 1,145.44 1,207.36 -153.48 2.64 3,019.61 60.10 359.96 2,516.75 1,217.63 1,288.69 -152.86 0.99 Leak Off and Formation Integrity Tests Leak Dens Fluid LO Eq Fluid Den off? Last Casing String Run. .Depth(ftKB) (Ib/gal) Fluid P Surf Applied(psi) (lb/gal) P LeakOff(psi). No Surface,2,409.2ftKB 2,409.0 9.60 WBM 950.0 18.03 2,031.9 Page 3/3 Report Printed: 12/1/2015 ' C) 00O O O U) 00 O O O O C) O O CO U) U) LU 11111 O ti I CO 1.0U) U) U) U) U) C) t1') to U) vt' D" CO CO U) U) U) it) LU LU LU LU LU U) U) U) Lt) U) U) .Y y y c sz E C 00 x i ., H H D 7 U) ca CO c) O U700 O O O O O O O O 0 0 0 0 0 0 0 0 0 0 p x .? U) C O N U) O U) O CU O U7 O CO O U) O U) O U) O U) O U) O C) fir[ ? ' f' O O O r N N M M - - U) U) C6 Cp N- I- CO OO 6) 6) O m E IL • U) O a- C 11, C) O CD CD O O O U) 000 O O �1 CON vr � C'') ' �- - O CO U) y U7 O i min N C') U) CO N- CO CO 6) d "a 1 N- = C a y .Q E a°3 6) 7 .. , Y O - NC') Nt U) CO I- CO CAO O ECT ^ L r N> 0.Q O U 0000 0000 000 O 000 CD ',-,-.) 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M f C o_ CO o o N CD c' Oa0 O II N (/)CD �co CI , E- N Q J a_i _I .0 .0 ` RI U) E 00 OOOh .C) m C CD p , O 0 co O6 O N ," OCr) C OF U100 V 0 y, a" i Fy, CO LO 0 D H V H Li vUi F- OD z U N r c pv.. _ �.i El.) u) p C L N L y p Q C: 0a ,.:; C 'N O)C7 3 Z�.Cr) C) 3 > �C 0 c CC ca N C � a) O - N ~ G *L +- O V `) a) w L x W 1 y n N_ DO C� > a N 0 w ON 7 C .L y U) LL. a) cam ++ ~ `° OO o 2 ._ .1c Q .C) U y ca i o E y 00 U W J 0 0 0 0 0 0 LO 0 0 Z I— N Y U I II v M M N N N- ,- N a) C) o65 w 3aflSS Ud E 8 I jw ".c,E • • Note to File CRU CD5-03 (PTD 2151460) January 4, 2016 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-03 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CD5-03. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-3/4" surface casing shoe is set in this well at -2,087' true vertical depth subsea', near the base of a 450-foot thick claystone and mudstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will lie within a radius of about 120' from the wellbore. 8. If injected wastes reach nearby well CRU CD5-09 or other nearby wells, surface casing and cement will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from CRU CD5-03 and seven nearby wells.' The discussion that follows is based on well logs and mud logs from these wells. Index maps are provided in Figures 1 and 2,below. The proposed annular disposal injection interval in these wells lies in the Torok and Seabee Formations within Section 7, T11N, R4E, Umiat Meridian, which is about 2-1/2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoes of these wells mainly lie between about -2,084' and to -2,193', near the base of a 450-foot thick interval that is dominated by claystone and mudstone and is continuous throughout the area. This claystone and mudstone interval will provide upper confinement for fluids disposed in the annulus of the well(see Figure 3,below). 1 Unless otherwise noted,all depths presented herein are expressed as negative integers,which represent feet,true vertical depth below mean sea level(mean low,low water). All thicknesses are expressed as positive integers,which represent true vertical feet.All horizontal distances are expressed as positive integers,which represent feet. 2 CRU CD5-04,CRU CD5-05,CRU CD5-09,CRU CD5-313,CRU CD5-314,CRU CD5-315,and Nuiqsut 1. CD5-03 Annular Disposal • • January 4, 2016 Note to File Page 2 of 7 The annulus open to the disposal interval extends downward from the surface casing shoe at-2,086' to the top of cement for the 7-5/8" casing string, which is estimated to be -4,137'. The portion of the open annulus that will most likely accept the injected waste is a 120-foot thick interval containing several 1-to 10-foot thick beds of siltstone and sandy siltstone that lie below the surface casing shoe between about - 2,253' and -2,426'. The aggregate thickness of these thin, potential receptor beds is about 34'. The siltstone and sandy siltstone beds are separated by thin claystone and mudstone intervals. Beneath the disposal interval are several intervals of claystone and mudstone that are continuous throughout the area. These intervals will provide lower confinement for any injected wastes. CD5-09 ci v q CD2-02 / CD2-21 CD2-09 26 ` - D2 , to-09L1 n. CD5-03 IL D2-74 CD2-73 Intermediate casing shoes — CD2-18 Ie, '7 J 3' V- J + Gp2 v, CD2-3113 -, CD2-59 A 'b;q. D2-78 CO2-75 L._..;- -p, : CD5-03 Annular Disposal • • January 4, 2016 Note to File Page 3 of 7 The 'A-mile radius area of review surrounding the proposed disposal interval in CD5-03 is highlighted on Figures 1 and 2 by two blue circles with tangential lines. The lower circle is centered at the location of the surface casing shoe, and the upper circle is centered on the calculated top of cement associated with the production casing string. For a clearer view, Figure 2 displays an enlarged index map. The bottom- hole locations visible on the map are also represented by gray-colored circles that measure 500' in diameter. �m 15000 �l.,900L ".1]000".'"1 1 Intermediate '1 � CD2-78 CD2-75 Iy,,-).-,. casing shoe `,,mow._ m /,,, '24IXq ''2,013 �.- -CD5-04 ; CD5-03 =17000 : 00 00 \,320 k;211300 "1 180CD2-541:1 CD5-09T .21000�9 X1+1 14000 NUK -SUT 1 i CD2-54 - CD r Quarter mile radius circles =,9. C W 2-33A Top of cementfr 13s, , 40,0 30 13 Intermediate � r 13014 �\ casing shoes °� CD5-03 �� . . „ p °°`, Open , ag k $ + 117ffiW t Annulus «; o -noon ,.- =°' CD5-05 ' ' CD4-079-. ,-leott Ail. X000 1 _,O ' 'N , Xg°°°CD2-33 3 tope 1]WO Surface casing shoe 1- ' -_,,. V01000 -1 4x'O CD5-04 , kms CD5-313,CD5-314, 0 1 mile ° - CD5-315 1 Figure 2. Enlarged CD5-03 Index Map (Depth tick-marks shown along well paths are measured depths. The magenta-colored line depicts the path of the cross-section displayed in Figure 3.) In CD5-03, the open annulus lies between -2,086' and -4,137', with the most likely waste-disposal interval between -2,250' and -2,380' (see Figures 2 and 3). Three wells, CD5-04, CD5-05, and CD5-09, are currently open to these same strata within the '/-mile radius area of review. The surface casing shoe of CD5-04 lies about 360' from the surface casing shoe of CD5-03. The surface casing shoe of CD5-05 lies about 1,000' from the surface casing shoe of CD5-03. The surface casing shoe of CD5-09, which is currently drilling, lies about 250' from the surface casing shoe of CD5-03. Figure 3, below, presents a south-to-north trending structural cross-section view of CD5-03 and nearby wells CD5-04 and CD5-05, which were logged to surface using gamma-ray and resistivity tools. Also included is nearby well CD5-313, which was logged to surface using gamma-ray, resistivity, and porosity tools. Resistivity measurements indicate that the base of permafrost occurs at about -1,200' in the CD5 Drill Site area,which is about 1,050' above the top of the proposed disposal interval. CD5-03 Annular Disposal • • January 4, 2016 Note to File Page 4 of 7 2150840 2150720 2150730 2151460 501032071400 181 h 501032071100 21(t 501032071200 40 H 501032071800 s 4 ► 4 — ► 4 _ ► N CONOCOPHILLIPS CONOCOPHILLIPSCONOCOPHILLIPS CONOCOPHILLIPS CRU CD5-313 360' CRU CD5-04 6971 CRU CD5-05 503' CRU CD5-03 362 FNL 2670 FEL 310 FNL 2497 FEL 316 FNL 2517 FEL 305 FNL 2451 FWL TWP:11 N-Range:4 E-Sec.18 TWP:11 N-Range:4 E-Sec.18 TWP:11 N-Range:4 E-Sec.18 TWP:11 N-Range:4 E-Sec.18 ' r ._ : - Mal ' _ I 1 O o =iii . i MA - i I- ' = j as-aim-i .i f 1.1„ —::::1 i l'-14,i';' F_ f Surface ' �a Base of Casing _• aE Plermafrost Shoes Upper _ -_ - Confining Interval _ - 1_1:1 r Most m€ 1 Likely-I I _ Disposal I Interval.,:: 1 iLowerConfiningBedsc Open i_ - Annuluso I _Tr t1 '� TD-15946 70=18878 7007900 70-20999 Figure 3. CD5-03 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; separation distance between wells is measured between the surface casing shoes) The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas, with minor amounts of ethane, propane, and butane. Mud logs were recorded in only two wells drilled in the vicinity of Drill Site CD5: CD5-313 and CD5-04, which are labeled on the map presented in Figure 2. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log) were -1,850'and -2,000', respectively. So, the entire proposed annular disposal interval contains methane gas. • CD5-03 Annular Disposal• January 4, 2016 Note to File Page 5 of 7 Unfortunately, oil shows are not recorded on the mud logs obtained in nearby wells CD5-313 and CD5- 04, apparently due to the use of oil-base drilling mud. In ARCO's Nuiqsut 1 exploratory well, located 4,000' to the northeast of the base of open annulus in CD5-03,the shallowest oil show was encountered at 3,990' MD(-3,930' TVDSS),with a second show encountered at 4,115' MD(-4,055' TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These characteristics suggest the presence of only trace to minor quantities of oil in the geologic strata that will be affected by annular disposal in CD5-03. At present, these shows are not believed to represent the presence of commercial quantities of oil. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order No. 18,which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Injected Fluid vs Affected Area Surrounding CD5-03 Wellbore (Assumptions:30%porosity,50%native fluid displacement,aggregate cylinder 34'high) 200 180 "..az.' 160 • 140 � E 120 • • c 100 •• • 80 -- — - • • • 60 aai w 40 — — Q • 20 — — 0 • 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid(barrels) Figure 4. CD5-03 Area Likely Affected by Annular Injection (Assuming piston-like,radial displacement of 50%of native formation fluids) The gamma ray curve recorded in CD5-03 indicates that about 34' of aggregate net siltstone and sandy siltstone are present within the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average porosity of about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste material lies within a radius of about 120' from the wellbore, assuming uniform, radial, piston-like displacement of the native formation fluid occurs(Figure 4). • CD5-03 Annular Disposal• January 4, 2016 Note to File Page 6 of 7 Injected Fluid vs Affected Area Surrounding CD5-03 Wellbore (Assumptions:30%porosity,50%native fluid displacement,elliptical aggregate cylinder 34'high) 600 w 550 — o 500 — bbl fid/ m - I 450 -1 E • 400 -a t 350 ' — • W 300 a ' t 250 - 200 • E 150 • , • d 100 • • i0 • u 50 • is o • 0 • 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid(barrels) Figure 5. Length of Semi-Major Axis (b)of Elliptical Cylinder Affected by CD5-03 Injection (Assuming piston-like,displacement of 50%of native formation fluids within in an elliptical cylinder having semi-minor axis length(a)of 35') The chart presented in Figure 5 provides an alternative estimate of the volume around CD5-03 that may be affected by the proposed annular disposal operations if horizontal permeability within the injection interval varies strongly in one direction. Again, the injection interval is assumed to be 34' thick, has 30% porosity, 50% of the native formation fluids are displaced by injected waste fluids, and horizontal permeability is assumed to be 10-fold smaller in a direction normal to that of the direction of primary permeability. If the injected waste fluids ultimately occupy an elliptical cylinder that has a semi-minor axis measuring 35' on either side of the CD5-03 wellbore, the semi-major axis of the affected elliptical cylinder may reach up to about 350' in length. The nearest surface casing shoe occurs in well CD5-09, which is located about 250' west of the surface casing shoe in CD5-03. So, with a strong west trending directional influence on horizontal permeability, fluids injected into the CD5-03 annulus may reach the open annulus beneath surface casing in CD5-09. However, the operator's surface casing cementing records from CD5-09 report 218 barrels of good cement returns to the surface.3 Summary The limited volume of rock that will be affected by this proposed annular disposal program contains methane gas, is situated beneath more than 1,200' of permafrost, and is bounded above and below by continuous layers of claystone and mudstone. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. 3 ConocoPhillips Alaska,Inc.,Daily Drilling Report for CRU CD5-09,report date November 23,2015. CD5-03 Annular Disposal January 4, 2016 Note to File Page 7 of 7 I recommen ap roving this proposed annular disposal within CRU CD5-03 to the limit of 35,000 barrels. r Steve Davies A (7/. 00 /4 Senior Petroleum Geologist • • Note to File CD5-03 (PTD 2151460, Sundry 315-762) Colville River Unit (Alpine Oil Pools) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD5-03). -- 10 3/4" Surface casing was cemented to surface successfully. No problems were reported. Approximately 250 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 10% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 10/23/2015, the pressure slope rises smoothly with several potential slope changes including a flattening to 16.5 ppg EMW and continues at a slightly shallower tapering slope to 17.2 EMW. Minimal fluid was pumped in at 2.6 bbl. The pressure declined slightly during the observation period and was steady during bleed back (volume bled back was not recorded by CPAI) and over the 10 min SI period to approx. 15.4 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. An open hole (preparing for the annulus 10.75 x 7.625") injectivity test LOT was performed 11/02/2015 with a calculated depth of the casing shoe of 2393 ft MD, 2157 ft TVD and an open hole to 5853 ft (3460 ft open) yielded a 14.8 ppg EMW. The test showed pressure rising within varying gradients to the sharp break over point at 14.8 ppg EMW. -- The 7.625" casing was run and successfully cemented with a two stage cement job. TOC for first stage estimated at 13340 ft MD, to TD 14340 ft MD. Cement job with no returns throughout. 2nd stage cement job pumped to lay cement from 6877 ft MD to 6977 ft MD (stage collar at 6977 ft MD). LOT of 7.625 inch shoe performed on 11/4/2015 produced a 12.5 ppg EMW @ casing (14341 ft MD, 7399 ft TVD). Cementing bumped plugs but no returns throughout. --There are multiple (3) wells within 1/4 mile radius of CD5-03 with all information already on file with AOGCC. The surface shoe of CD5-04 is closest, about 360' distant. CD5-05 is 1000 ft. AD is expected to be applied for on multiple wells on CD5. CPAI is therefore constructing the CD5 wells to be compliant with AD regulations. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC LAY� January 6, 2016 G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\160106_CD5-03 note to file.doc w ■ ED • STATE OF ALASKA • DEC 18 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION An'4r'-C1 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil RI Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAc 25.105 2OAAc 25.110 Development II Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp. or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 11///2015 tW 215-146/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 •10/19/2015 50-103-20718-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 304'FNL,2478'FEL,Sec. 18,T11N, RO4E, UM •11/13/2015 CRU CD5-03 Top of Productive Interval: 9. Ref Elevations: KB: 10.`13 17. Field/Pool(s): 4882'FNL, 572'FEL, Sec. 31,TO12N, R004, UM GL:,5-1.1 BF: Maii Colville River Unit/Alpine Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4301'FNL, 3685' FEL, Sec. 30,T12N, RO4E, UM n/a ASRC NPR4,ASRC NPR2 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 349500.86 y- 5965905 Zone-4 20,999/7,331 932128, 932671,932193 TPI: x- 351588,96 y- 5977126,24 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 348572 y- 5983049 Zone- 4 none 1345 MD/1321 TVD 5. Directional or Inclination Survey: Yes CK(attached) No [ ] 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20 94 H-40 30 110 36 110 42 10 yds. 10 3/4 45.5 L-80 36 2401 36 2160 13 1/2 1,059 sx 11.0 ppg G,273sx 15 7 5/8 29.7 L-80 36 14340 36 7399 9 7/8x11 Stage 1:424 sx 15.8 ppgG,Stage 2 449 sx 15.8 ppqG 4 1/2 12.6 L-80 14300 20999 7394 7341 6 1/2 Ported Liner 24. Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 14167 13723/7247 Slotted Liner from 18,513-20,933=MD 7385-7332=TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No RI Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift,etc.): 11/25/2015 Gas Lifted to facility Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/26/2015 12 hrs Test Period -0- 392 367 90 100% 775 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 1R4 1097 24-Hour Rate -0 827 641 177 n/a Form 10��07 e7ed 1/2015 VT` /16/I"6 /� N NUED ON PAGE 2 RBDMSZ DEC 3 0 2015 Submit ORIGINIAL only^ • • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No El If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No RI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1345 1321 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 14,341 7399 information, including reports, per 20 AAC 25.071. C-30 2705 K-3 5921 3705 6431 3936 ,Ibian97 7226 4295 \Ibian 96 9531 5340 IRZ 13298 Kalubik 13511 7128 Kuparuk C 13793 7225 Alpine C 14050 7291 Alpine A 14262 7323 Formation at total depth: /llpZiNe_A MI 31. List of Attachments: Schematic,Summary of Daily Operations,difinitive survey,cement report Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, Paleontological reportt production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correctto t,e bet of,my knowledge. Contact: Weifenq Daia263-4324 �` 'ti e` 1 ^1 Email: weifenq.DaiAconocophillips.com Printed Name: Chip Alvord Title: Alaska Drilling Manager Signature: Phone: 265-6120 Date: 114«(2-* 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 la: 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 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 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 11/2015 Submit ORIGINAL Only WNS PROD • CD5-03 ConoccPhilhip5 _ N Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r�ri,.4m r,, 501032071800 ALPINE PROD 94.22 19,183.81 20,999.0 --- w.. Continent H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD5-03,12118/201582643 AM SSSV NIPPLE Last WO. 36.83 11/20/2015 Vertical schematic(aCtUalj Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ----- Last Tag' Rev Reason NEW WELL.GLV C/O lehalli 12/17/2015 HANGER 31.5 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Conductor 20 19.000 35.9 115.0 115.0 78.60 L-80 Welded _..................................._.............,.........................4 P......._........Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Surface OD 3/4 9.950 35.9 2,393.4 2,156.9 45.50 L-80 Hyd 563 " uLuk11M11eia Casio Descri t OD(in) ID(in) TopftKB Set Depth ftKB Set Depth TVD Wt/LenGrade TopThread I s pion ( ) p (ftKB) p (TVD)... (I... .inn.nn�Intermediate 7 5/8 6.875 34.5 14,340.7 7,399.0 29.70 L80 BTCM Conductor;35.9-115.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread X0 Reducing;121.6 Production Liner 4 1/2 3.958 14,152.6 20,990.0 7,332.1 12.60 L-80 IBT-M Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 14,152.6 7,379.7 81.16 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.250 14,174.0 7,382.8 81.85 NIPPLE BAKER RS PACKOFF NIPPLE 4.000 14,176.3 7,383.2 81.93 HANGER BAKER FLEX-LOCK LINER HANGER 4.170 14,191.1 7,385.2 82.41 XO Reducing Cross over,5"BTC-M x 4-1/2"Hyd 563 3.920 14,801.1 7,395.0 91.64 SLEEVE CAMCO SLIDING SLEEVE'D'PROFILE,OPEN 2.750 DOWN 14,871.0 7,393.1 91.59 FRAC PORT FRAC SLEEVE#9,4 1/2",Ball Act,2.063"(2.05"ID) 2.050 Surface;35.9-2,393.4 15,617.8 7,390.1 89.55 FRAC PORT FRAC SLEEVE#8,4 1/2",Ball Act,2.000"(1.954"ID) 1.954 GAS LIFT;6,666.7 16,487.4 7,394.5 91.11 FRAC PORT FRAC SLEEVE#7,4 1/2",Ball Act,1.938"(1.8901D) 1.890 17,099.7 7,385.4 89.93 FRAC PORT FRAC SLEEVE#6,4 1/2",Ball Act,1.875"(1.83"ID) 1.830 17,711.1 7,380.4 90.39 FRAC PORT FRAC SLEEVE#5,4 1/2",Ball Act,1.813"(1.77"ID) 1.770 GAS LIFT;10,045.0 18,451.5 7,383.3 88 23 FRAC PORT FRAC SLEEVE#4,4 1/2",Ball Act,1.75"(1.71"ID) 1.710 Tubing Strings E'. Tubing Description Stnng Ma...ID(In) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 31.5 14,167.0 7,381.8 9.30 L-80 EUE Completion Details GAS LIFT;13,602.9 1 Nominal ID Top(ftKB) Top(TVD)(ftKB( Top Incl(°) Item Des Com (in) 31.5 31.5 0.12 HANGER FMC HANGER 3.958 GAUGE;13,662.1 - 121.6 121.6 0.42 XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE Brd Pin Drifted 2.992 2.91" 553.5 553.4 3.74 NIPPLE CAMCO LANDING DS NIPPLE 2.875 13,662.1 7,254.2 70.00 GAUGE 3-1/2",SLB Solid Gauge Mandrel with I-wire 2.913 XO Threads;13,719.0 PACKER;13,723.4 - 13,723.4 7,274.4 71.56 PACKER BAKER PREMIER PACKER 2.880 xo Threads;13,731.4 I 13,756.0 7,284.5 72.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 ;1 14,149.7 7,379.2 81.07 LOCATOR LOCATING SUB 3.000 14,150.4 7,379.3 81.09 SHOE BAKER WLEG 2.970 Perforations&Slots LOCATOR;14,149.7 Shot Dens SHOE;14,150.4 Top(TVD) Bim(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 18,513.1 20,933.5 7,385.4 7,332.8 11/16/2015' SLOTS 2 X 1/4"X 16 SLOTS/FT 20,975.0 20,964.7 7,332.3 7,332.2 11/16/2015 PERFP PERF PUP 36 -5"HOLES Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com Intermediate;34.5-14,340.7 ` 1 6,666.7 4,113.0 Cameo KBMG 1 GAS LIFT GLV BK-5 0.188 2,023.0 11/23/2015 2 10,045.0 5,641.4 Cameo KBMG 1 GAS LIFT GLV BK-5 0.188 1,913.0 11/22/2015 3 13,602.9 7,233.3 Cameo KBMG 1 GAS LIFT OV BEK 0.250 0.0 11/22/2015 4 Notes:General&Safety End Date Annotation NOTE: Ii II 11I ]I 3i SLOTS;18,513.1-20,933.5 1 PERFP;20,975.0-20,964.7 A. __ Production Liner;14,152.8- 20.990.0 . tperations Summary (with Timelog epths) 'II Wel CD5-03 Conocattillips Ails A.s Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKB) End Depth(ftKB) 10/18/2015 10/18/2015 0.75 MIRU MOVE MOB P PJSM-review rig move check list. 0.0 0.0 09:00 09:45 Raise cattle shoot,Otter slide and off driller side door.Jack and move pipe shed away from sub.SIMOPS- Electrician disconnect lines from sub. 10/18/2015 10/18/2015 0.25 MIRU MOVE MOB P Move pits/motors away from sub. 0.0 0.0 09:45 10:00 10/18/2015 10/18/2015 1.00 MIRU MOVE MOB P Skid floor and move into position. 0.0 0.0 10:00 11:00 Raise rear wind walls and support feet 10/18/2015 10/18/2015 0.75 MIRU MOVE MOB P Jack rig sub up and pull off of CD5- 0.0 0.0 11:00 11:45 315. Remove Tie bars on sub base and turn tires to crab down well pad. 10/18/2015 10/18/2015 2.75 MIRU MOVE MOB P Crab rig sub down pad.Spot rig sub 0.0 0.0 11:45 14:30 over CD5-03 conductor. 10/18/2015 10/18/2015 1.00 MIRU MOVE MOB P Spot rig sub over CD5-03 conductor. 0.0 0.0 14:30 15:30 10/18/2015 10/18/2015 1.50 MIRU MOVE MOB P PJSM on skidding rig floor out. Skid 0.0 0.0 15:30 17:00 rig floor into drilling position. Lower rig support feet and cellar wind walls into position. Shim and level rig.Spot Pits and Motor complexes into position. Move pipe shed next to sub and level. Work on pre-spud check list.connect service lines at Interconnect.Spot Ball Mill and Pipe shed next to rig. 10/18/2015 10/18/2015 1.50 MIRU MOVE RURD P PU Riser,insulate under rig floor, MU 0.0 0.0 17:00 18:30 Mud pump lines and prime. Test gas alarms. NU Riser, flowline,hole fill and bleeder. RU to High-line. Note: rig on High-line power at 1830 hrs. Review and finalize Rig Acceptance check list. Note:Rig accepted on day work at 1830 hrs, 10/18/2015. Calibrate block height. Survey True north and wellbore heading with surface Gyro. Measure rig elevations. 10/18/2015 10/18/2015 3.50 MIRU MOVE RURD P Load 18 jts of 5"HWDP in shed.Hook 0.0 0.0 18:30 22:00 up valves on conductor.Take on 9.0 ppg DRILPLEX mud in pits. Install air boot on riser for drip pan. Calibrate block height. Survey True north and wellbore heading with surface Gyro. Measure rig elevations. 10/18/2015 10/18/2015 1.00 MIRU MOVE SFTY P Hold pre-Spud salty mtg and review 0.0 0.0 22:00 23:00 checklist. 10/18/2015 10/19/2015 1.00 MIRU MOVE BHAH P PJSM and MU BHA#1 to 29'. 0.0 29.0 23:00 00:00 10/19/2015 10/19/2015 1.00 MIRU MOVE BHAH P Continue MU BHA#1 from 29'to 89'. 29.0 89.0 00:00 01:00 10/19/2015 10/19/2015 1.00 MIRU MOVE BHAH P Orient Motor/MWD. RU and hang 89.0 89.0 01:00 02:00 sheaves for running gyro survey tools. Page 1/26 Report Printed: 12/17/2015 operations Summary (with Timelogtpths) &W CD5-03 ie'uacoPhiilips Al Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1 0/1 9/2015 10/19/2015 0.75 MIRU MOVE SEQP P Fill hole with 9.0 ppg Drillplex mud and 89.0 89.0 02:00 02:45 lines with water.Check for leaks- good. RIH and tag bottom at 115'.Set down with 9K lb to confirm. PU=SO= 80K lb. PU to 89' 10/19/2015 10/19/2015 0.25 MIRU MOVE WASH P MU stand of 5"HWDP. Wash to 89.0 115.0 02:45 03:00 bottom at 115'with 460 gpm,450 psi, 40 rpm and 1K TQ 10/19/2015 10/19/2015 1.50 SURFAC DRILL DDRL P Spud well and drill ahead from 115'to 115.0 212.0 03:00 04:30 212' ADT 1.21 hrs. 10/19/2015 10/19/2015 0.25 SURFAC DRILL SRVY P Run check shot survey with gyro tool. 212.0 212.0 04:30 04:45 10/19/2015 10/19/2015 1.00 SURFAC DRILL BHAH P POOH to 89'and stand back stand of 212.0 192.0 04:45 05:45 HWDP. Continue to MU BHA to 192' with NMDC,Jars and STAB. PU= SO=85K lb. 10/19/2015 10/19/2015 0.25 SURFAC DRILL WASH P Wash to TD at 212'and orient tool 192.0 212.0 05:45 06:00 face. 10/19/2015 10/19/2015 6.00 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 212' 212.0 563.0 06:00 12:00 to 563'. ADT=4.87 hrs,ART=3.34 hrs,AST= 1.53 hrs. TVD=593'. PU= 95K,SO=90K, ROT=92K lb. TQ on/off=4.5K/2.5K ft-Ib, Gyro surveys at 109', 181',286',379', 456',547'and 10/19/2015 10/20/2015 12.00 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 563' 563.0 1,780.0 12:00 00:00 to 1,780'. ADT=7.03 hrs,ART=3.23 hrs,AST=3.80 hrs. TVD=1,713'. PU= 122K,SO= 115K, ROT= 120K lb. TQ on/off=15.0K/2.0K ft-Ib, Gyro surveys at 640',743'and 10/20/2015 10/20/2015 12.00 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 1,780.0 2,326.0 00:00 12:00 1,780' to 2,326'. ADT=9.11 hrs, ART=2.38 hrs,AST=6.73 hrs. TVD= 2,116'. PU=125K,SO= 112K, ROT= 119K lb. 10/20/2015 10/20/2015 1.50 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 2,326.0 2,409.0 12:00 13:30 2,326' to 2,409'. ADT=1.38 hrs, ART=0.75 hrs,AST=0.63 hrs. TVD= 2,166'. PU= 120K,SO=110K, ROT= 115K lb. 10/20/2015 10/20/2015 1.50 SURFAC CASING CIRC P Survey at 2,409'md,pump 40 bbl nut 2,409.0 2,409.0 13:30 15:00 plug sweep,CBU 3X with 790 gpm, 2,080 psi,60 rpm,2.8K TQ. 10/20/2015 10/20/2015 0.25 SURFAC CASING OWFF P Flow-chk for 15 min with 15 rpm,3.9K 2,409.0 2,409.0 15:00 15:15 TQ-static. 10/20/2015 10/20/2015 0.25 SURFAC CASING PMPO P Pump OOH from 2,409'-2,270'and 2,409.0 2,270.0 15:15 15:30 with 790 gpm,2,150 psi without rotary -hole packing off. Rotate at 60 rpm, 5.3K TQ and still packing off. 10/20/2015 10/20/2015 0.25 SURFAC CASING REAM T Ream back to bottom from 2,270- 2,270.0 2,409.0 15:30 15:45 2,409'with 790 gpm,2,150 psi,60 rpm,3.6K TQ. Page 2/26 Report Printed: 12/17/2015 operations Summary (with Timelog epths) { &Wells CD5-03 COMCCIPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/20/2015 10/20/2015 1.25 SURFAC CASING CIRC T Circ&cond with 2X- 790 gpm,2,000 2,409.0 2,409.0 15:45 17:00 psi,60 rpm,3.0K TQ,with 2X-40 bbl nut plug sweeps. 10/20/2015 10/20/2015 2.00 SURFAC CASING PMPO P Flow chk with 10 rpm- static. Pump- 2,409.0 1,874.0 17:00 19:00 OOH from 2,409'to 1,874'with 790 gpm,2,040 psi and no rotary. Blow down TD. 10/20/2015 10/20/2015 3.25 SURFAC CASING TRIP P POOH from 1,874'to BHA at 196'. 1,874.0 196.0 19:00 22:15 Flow chk at 744'-static. Work thru tight spot from 367'-343'. Pull 50K over and worked thru.Work thru spot 3X with no over pull during the third pass. Tight spots at 1,829', 1,807', 1,340', 460'-25-35K over pull. 364'-343'-50K lb OP. 10/20/2015 10/21/2015 1.75 SURFAC CASING BHAH P PJSM. LD BHA from 196'to 88'in 30'- 196.0 88.0 22:15 00:00 39'sections. 10/21/2015 10/21/2015 0.75 SURFAC CASING BHAH P Continue to LD BHA from 88'. 88.0 0.0 00:00 00:45 10/21/2015 10/21/2015 0.75 SURFAC CASING BHAH P Clean and clear floor.RD 5"DP 0.0 0.0 00:45 01:30 elevators. PU casing tools and equipment. 10/21/2015 10/21/2015 1.00 SURFAC CASING RURD P RU Volant CRT tool. RU 4'bail 0.0 0.0 01:30 02:30 extensions and 10-3/4"elevators.RU casing tools. MU floor valve on XO. 10/21/2015 10/21/2015 7.25 SURFAC CASING PUTB P PJSM. Run 10-3/4"Silver Bullet float 0.0 2,393.0 02:30 09:45 shoe,2 jts 10-3/4"BTCM casing, HES float collar,2 jts 10 3/4"BTC casing. Baker-Lok first 3 connections.Check floats-okay. Continue running 10- 3/4",45.5 lb/ft, L-80, BTCM,R3 casing to 602'(15 jts including shoe track). Install 42.75'BTCM x H563 XO joint followed by 40 joints 10-3/4", 45.5 lb/ft, L-80, H563,R3 to 2,393.4' md. Avg MU torque=7,700 ft-lb for BTCM when made up to the mark using Run&Seal thread dope, 16,000 ft-lb torque for H563 connections with Seal Guard ECF thread dope. PU= 140K,S0= 105K Cents(Centek-10-3/4"bow springs, 55 total): 1 -10'from shoe on stop collar, 1 -30'from pin on jt#2 on stop, 1 -20'from pin on jt#3, 1 -free floating on joints#4-54 10/21/2015 10/21/2015 0.50 SURFAC CEMENT RURD P BD Top drive and RU cement lines to 2,393.0 2,393.0 09:45 10:15 Volant tool/cement swivel. 10/21/2015 10/21/2015 3.00 SURFAC CEMENT CIRC P Circ&cond mud for cement job Stage 2,328.0 2,328.0 10:15 13:15 flow rate from 1-4.5 bpm,320-330 psi bpm,reciprocate pipe 12'. (SIMOPs-RD casing tools and equipment. RD 4'bail extensions, 10.75"elevators for TD and LD.Clean &clear floor. Page 3/26 Report Printed: 12/17/2015 operations Summary (with Timelog•pths) &Wells CD5-03 Conoco hiitiips A1.k.$ Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 10/21/2015 10/21/2015 3.00 SURFAC CEMENT CMNT P PJSM. Surface cement job: Dowell 2,328.0 2,328.0 13:15 16:15 pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 75 bbls 11 ppg Mud Push II, Drop bottom plug, Dowell pump 26 bbls of 11.0 ppg Scavenger,360 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm, 225-460 psi.Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 3.3 bpm/390-180 psi. Drop top plug. Dowell pump 10 bbls H2O.Rig displace with 211.3 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 580 psi,decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min.Check floats-good. Full returns throughout 250 bbls good cement back to surface. Reciprocated pipe with 12' stroke until MudPush exited shoe. Stopped reciprocating due to excess drag and hole appearing to getting sticky.CIP at 16:03 hrs. 10/21/2015 10/21/2015 0.25 SURFAC CEMENT RURD P Flush surface riser and Annular with 0.0 0.0 16:15 16:30 black water. Shut in annular and monitor annulus pressure.Check pressure every 10 min for one hour and every 30 min there after.Pressure = 11 -12 psi 10/21/2015 10/21/2015 1.50 SURFAC CEMENT RURD P BD and RD cement lines. RD Volant 0.0 0.0 16:30 18:00 CRT.Clear and clean rig floor. 10/21/2015 10/21/2015 0.50 SURFAC CEMENT PULD P PJSM. PU 5"DS50 Hi-Torque double 0.0 0.0 18:00 18:30 shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC. 10/21/2015 10/21/2015 0.75 SURFAC CEMENT SVRG P Service Rig:Top drive,drawworks, 0.0 0.0 18:30 19:15 Iron roughneck and pipe skate. 10/21/2015 10/22/2015 4.75 SURFAC CEMENT PULD P PJSM. PU 13 stands of 5"DS50 Hi- 0.0 0.0 19:15 00:00 Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC. 10/22/2015 10/22/2015 8.00 SURFAC CEMENT PULD P PJSM. PU 34 stands of 5"DS50 Hi- 0.0 0.0 00:00 08:00 Torque double shoulder DP and MU in mouse hole. Break in new connection per manufacturer specs and rack back in derrick while WOC(47 total). Note: Pressure on annulus-11 psi at 08:00 hrs. Bled off pressure and open bag. No flow or drips observed. 10/22/2015 10/22/2015 0.25 SURFAC CEMENT OWFF P Flo-chk-static.PJSM for ND riser 0.0 0.0 08:00 08:15 10/22/2015 10/22/2015 0.75 SURFAC CEMENT RURD P Backout and LD landing joint. 0.0 0.0 08:15 09:00 SIMOPs-Perform BWM on lower pipe rams. 10/22/2015 10/22/2015 2.50 SURFAC CEMENT NUND P ND riser,flow line,and drain, ND 20" 0.0 0.0 09:00 11:30 annular, Page 4/26 Report Printed: 12/17/2015 DriWwsg Iterations Summary (with Timeloggepths) CD5-03 ConoxoPhdlips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 0.75 SURFAC CEMENT NUND P Split starting head and remove flange. 0.0 0.0 11:30 12:15 Remove slip segments from conductor. 10/22/2015 10/22/2015 0.50 SURFAC CEMENT NUND P Raise rear wind walls and remove 0.0 0.0 12:15 12:45 annular and starting head from cellar. Bring in new RCD head and controller. 10/22/2015 10/22/2015 0.75 SURFAC WHDBOP NUND P Install speed head and test metal to 0.0 0.0 12:45 13:30 metal seals to 1,000 psi for 30 min- good. PJSM for NU. 10/22/2015 10/22/2015 1.50 SURFAC WHDBOP MPDA T NU BOPE. Remove old RCD and 0.0 0.0 13:30 15:00 dutch flange for change out. 10/22/2015 10/22/2015 1.00 SURFAC WHDBOP SVRG P Perform BWM(between wells 0.0 0.0 15:00 16:00 maintenance)on BOPE.Open ram doors&inspect. 10/22/2015 10/22/2015 5.00 SURFAC WHDBOP MPDA T NU new RCD head, MPD Orbit and 2" 0.0 0.0 16:00 21:00 valve assembly, 1502 union valves, control box,KetchCan and drain hoses. Measure stack component RKB distances. Attempt to install trip nipple,appeared short and called out welder. 10/22/2015 10/22/2015 1.75 SURFAC WHDBOP RURD P Line up to test BOPE. PU, install 5" 0.0 0.0 21:00 22:45 test joint and test plug. Fill lines and stack with H2O. 10/22/2015 10/22/2015 0.75 SURFAC WHDBOP MPDA T Continue to RU new Trip nipple,flow 0.0 0.0 22:45 23:30 line,hole fill and bleed off line.Center stack. 10/22/2015 10/23/2015 0.50 SURFAC WHDBOP BOPE P Test BOPE with 5"test its-Test 0.0 0.0' 23:30 00:00 Annular and HCR choke/kill 250/2,500 psi and chart for 10 min. Upper 3-1/2" x 6"VBR's, blind rams,Auto IBOP, (Choke valves#1, 12, 14)-14,HCR choke/kill, Demco on Kill, to 250/3500 psi for 10 min.Testing witnessed by Chuck Scheve of the AOGCC. 10/23/2015 10/23/2015 4.00 SURFAC WHDBOP BOPE P Continue to test BOPE with 5"test jt- 0.0 0.0 00:00 04:00 Upper/Lower 3-1/2"x 6"VBR's, Manual IBOP,Choke manifold valves #2-11, HCR choke/kill,manual choke/kill on stack,needle valve,dart valve above#1, FOSV made up to NC50 and DS50 XOs to 250/3500 psi for 10 min. Draw down test on Degasser, manual/super choke to 1100 psi.Accumulator test, Int=3,075 psi/1,400 psi after function,37 sec to first 200 psi, 214 sec to full system psi.4-N2 bottles= 1,975 psi. Function tested rams from remote panel-good. Gas alarms tested-good.(Note Csg gauge on Super Choke panel failed, battery was replaced and back in service). Test witnessed by Chuck Scheve of the AOGCC. 10/23/2015 10/23/2015 0.50 SURFAC WHDBOP RURD P Blow down choke manifold,Choke 0.0 0.0 04:00 04:30 and Kill lines and RD BOP test equip. Page 5/26 Report Printed: 12/17/2015 operations Summary (with Timelo Depths) &Wefts CD5-03 Phillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 10/23/2015 10/23/2015 1.50 SURFAC WHDBOP MPDA P ND Flow line,pull Trip Nipple and 0.0 0.0 04:30 06:00 install MPD test plug. Fill MPD lines with water and test equipment to 200/ 1,200 psi-good. Blow down lines. 10/23/2015 10/23/2015 1.00 SURFAC WHDBOP MPDA P PJSM. Install 2X MPD elements and 0.0 0.0 06:00 07:00 rack back in derrick. 10/23/2015 10/23/2015 0.50 SURFAC WHDBOP MPDA P NU trip nipple,bleeder, hole fill lines 0.0 0.0 07:00 07:30 and flow line.SIMOPs: Pull MPD test plug and install 10"WB. 10/23/2015 10/23/2015 1.25 SURFAC CEMENT BHAH P PU 9-7/8"x 11"RSS BHA #2 tools to 0.0 0.0 07:30 08:45 rig floor.Set mouse hole. 10/23/2015 10/23/2015 1.50 SURFAC CEMENT BHAH P MU BHA #2 to 139'.PU=SO=75K 0.0 139.0 08:45 10:15 10/23/2015 10/23/2015 1.50 SURFAC CEMENT TRIP P RIH with HWDP and hydraulic Jars to 139.0 2,131.0 10:15 11:45 720'. RIH with 5"DP to 2,131'. PU= 125K,SO= 110K lb. 10/23/2015 10/23/2015 0.25 SURFAC CEMENT DHEA P Pulse test MWD with 450 gpm,910 2,131.0 2,131.0 11:45 12:00 psi. 10/23/2015 10/23/2015 0.50 SURFAC CEMENT CIRC P CBU with 765 gpm, 1,950 psi,30 rpm, 2,131.0 2,131.0 12:00 12:30 3.8K TQ 10/23/2015 10/23/2015 1.75 SURFAC CEMENT PRTS T Blow down TD.RU and test 10-3/4" 2,131.0 2,131.0 12:30 14:15 csg to 3,500 psi for 30 min and chart record. Pressure bleeding off from the UPRs. Bleed off,inspect and function rams several times.Pressure up to 3,000 psi and not holding. Check surface equipment for leaks(ok), found pressure sensor bladder was low. 10/23/2015 10/23/2015 0.75 SURFAC CEMENT PRTS P Pressure up to 3,600 psi,monitored 2,131.0 2,131.0 14:15 15:00 and recorded on a chart and pressure bled to 3,480 psi in 30 minutes(120 psi or 3.3%). Bleed off pressure and RD test equip. Blow down lines. 10/23/2015 10/23/2015 1.00 SURFAC CEMENT SLPC P Slip and cut 60'of drilling line. 2,131.0 2,131.0 15:00 16:00 10/23/2015 10/23/2015 1.50 SURFAC CEMENT SVRG P Service TD, Iron roughneck and 2,131.0 2,131.0 16:00 17:30 drawworks.Calibrate block height. 10/23/2015 10/23/2015 2.75 SURFAC CEMENT COCF P Wash and ream from 2,131'to 2,409' 2,131.0 2,409.0 17:30 20:15 with 545 GPM, 1,320 psi,50 rpm, 5.6K TQ. Tag solid cement 2,297.FC at 2,304',FS at 2,391'. Drill out cement with 550 gpm, 1,230 psi,40 rpm,6.8K TQ. 10/23/2015 10/23/2015 0.50 SURFAC CEMENT DDRL P Drill 20'of new formation with 9-7/8" 2,409.0 2,429.0 20:15 20:45 hole from 2,409'to 2,429 and begin displacing hole to 9.6 ppg LSND mud at 550 gpm, 1,230 psi,50 rpm,5.2K TQ.Continue circulating until MW in/out=9.6 ppg.Pull back inside 10- 3/4"csg at 2,379'for LOT. 10/23/2015 10/23/2015 0.75 SURFAC CEMENT LOT P PJSM,blow down TD. RU lines and 2,379.0' 2,379.0 20:45 21:30 test equip. Perform LOT to 17.2 ppg EMW with 9.6 ppg LSND and 850 psi surface pressure. Shut in and monitor for 10 min. 10/23/2015 10/23/2015 0.25 INTRM1 DRILL RURD P RD test equip and blow down lines. 2,379.0 2,379.0 21:30 21:45 Page 6/26 Report Printed: 12/17/2015 Operations Summary (with Timelo W Depths) ens CD5-03 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/23/2015 1.25 INTRM1 DRILL DDRL P Wash and ream back to bottom at 2,379.0 2,507.0 21:45 23:00 2429'. Drill ahead 9-7/8"Intermediate hole from 2,429'to 2,507'. 10/23/2015 10/23/2015 0.50 INTRM1 DRILL CIRC P Drop 1.25"reamer activation ball and 2,507.0 2,409.0 23:00 23:30 pump down with 50 gpm, 180 psi(bit at 2,507'and UR blades at 2,412'). Shear out at 1,130 psi,increase flow rate to 550 gpm. TRPM=4,420 dropping to 3,790,pump pressure= 1,580 psi,dropping to 1,200 psi after, indicating flow diverting thru reamer. PU without rotation and tag csg shoe with UR blades with 10K lb.confirming under-reamer open. 10/23/2015 10/24/2015 0.50 INTRM1 DRILL DDRL P RIH and drill ahead 9-7/8" 2,409.0 2,557.0 23:30 00:00 Intermediate hole from 2,507'to 2,557.' ADT= 1.5 hrs,TVD=2,249' PU= 125K,SO=115K, ROT=118K, 4.8K TQ,ECD: 10.32 ppg SPRs-2,410'md,2230 hrs,9.6 ppg MP#1: 30-80,40-120 MP#2: 30-80,40-120 10/24/2015 10/24/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 2,557' to 2,557.0 4,037.0 00:00 12:00 4,037'. ADT=8.93 hrs,TVD=2,923'. PU=140K,SO= 114K,ROT=125K, TQ on/off=6.9K/3.4K ft-Ib, ECD- 10.82 ppg SPRs-3,732'md,09:00 hrs MP#1: 30-140,40-190 MP#2: 30-140,40-180 10/24/2015 10/25/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 4037' to 4,037.0 5,360.0 12:00 00:00 5,360'. ADT=9.33 hrs,TVD= 3,521'. PU= 155K,SO= 125K, ROT= 135K, TQ on/off=8.9K/5.8K ft-lb,ECD- 11.22 ppg SPRs-5,330'md,22:45 hrs MP#1: 30-170,40-210 MP#2: 30-170,40-210 10/25/2015 10/25/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 5,360' to 5,360.0 6,783.0 00:00 12:00 6,783'. ADT=9.42 hrs,TVD= 4,164'. PU= 185K,SO= 125K, ROT= 147K, TQ on/off= 13.5K/8K ft-Ib,ECD-10.92 ppg SPRs-6,367'md,08:40 hrs MP#1: 30-180,40-230 MP#2: 30-180,40-230 10/25/2015 10/26/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 6,783' to 6,783.0 7,813.0 12:00 00:00 7,813'. ADT=9.33 hrs,TVD= 3,521'. PU= 190K,S0= 135K, ROT= 155K, TQ on/off= 15.5K/11.2K ft-lb,ECD- 10.75 ppg SPRs-5,330'md,22:45 hrs MP#1: 30-270,40-320 MP#2: 30-270,40-320 Page 7/26 Report Printed: 12/17/2015 Drilling Operations Summary (with Timelog•pths) CD5-03 ConocorPhillips Ak ka Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2015 10/26/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 7,813' to 7,813.0 9,197.0 00:00 12:00 9,197'. ADT=9.08 hrs,TVD= 5,257'. PU=230K,SO= 140K, ROT= 169K, TO on/off= 19.0K/11.5K ft-lb, ECD- 10.82 ppg SPRs-6,910'md,09:20 hrs MP#1: 30-280,40-320 MP#2: 30-270,40-320 10/26/2015 10/27/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,197' to 9,197.0 10,506.0 12:00 00:00 10,506'. ADT=8.91 hrs,TVD= 5,849'. PU=245K,SO= 145K,ROT= 180K,TQ on/off=20.5K/18.0K ft-lb, ECD-10.75 ppg SPRs-10,225'md,21:00 hrs MP#1: 30-320,40-380 MP#2: 30-320,40-380 10/27/2015 10/27/2015 12.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole f/10,506'to 10,506.0 11,633.0 00:00 12:00 11,633'MD 6,354'TVD. ADT=9.48 hrs, ECD 10.73,800 gpm,2600 psi, PU=235 k,SO= 157 k, ROT= 189 k, TQ on/off=25.5/13.5 k ft-lb SPRs-11,351'md,9:20 hrs MP#1: 30-350,40-410 MP#2: 30-360,40-410 10/27/2015 10/27/2015 10.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole f/11,633'to 11,633.0 12,757.0 12:00 22:30 12,757'MD 6,866'TVD. ADT=7.84 hrs, ECD 10.77,800 gpm,2850 psi, PU=255 k,SO= 173 k,ROT=200 k, TQ on/off=26.2/15.5 k ft-lb SPRs-12,570'md,20:30 hrs MP#1: 30-350,40-410 MP#2: 30-350,40-410 10/27/2015 10/27/2015 0.75 INTRM1 DRILL CIRC P Circ B/U w/800 gpm,2800 psi, 160 12,757.0 12,757.0 22:30 23:15 rpm,20 k trq.SIMOPS-PJSM on install MPD bearing 10/27/2015 10/27/2015 0.25 INTRM1 DRILL OWFF P F/C w/15 rpm @ 17 k trq(static) 12,757.0 12,757.0 23:15 23:30 SIMOPS-N/D hoses from trip nipple 10/27/2015 10/28/2015 0.50 INTRM1 DRILL MPDA P N/D trip nipple&Install RCD element 12,757.0 12,757.0 23:30 00:00 10/28/2015 10/28/2015 0.50 INTRM1 DRILL MPDA P Cont.to remove trip nipple&install 12,757.0 12,757.0 00:00 00:30 MPD bearing. Establish circ&break in new bearing. 10/28/2015 10/28/2015 2.50 INTRM1 DRILL DDRL P Drill 9 7/8"X 11"hole f/12,757'to 12,757.0 12,965.0 00:30 03:00 12,965'(Increase mud wt from 9.6 ppg to 10.4 ppg on the fly) 10/28/2015 10/28/2015 0.50 INTRM1 DRILL RGRP T Observe mud leaking into cellar. P/U 12,965.0 12,965.0 03:00 03:30 off of bottom&reconfigure cap on flow line 10/28/2015 10/28/2015 8.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole f/12,965'to 12,965.0 13,608.0 03:30 12:00 13,608'MD 7,232'TVD. ADT=7.07 hrs, ECD 11.55,800 gpm,3050 psi, PU=270 k,SO= 155 k,ROT=200 k, TQ on/off=29/19.5 k ft-lb SPRs-13,225'md,6:30 hrs MP#1: 30-580,40-660 MP#2: 30-600,40-660 Page 8/26 Report Printed: 12/17/2015 el .. Operations Summary (with Timelog Depths) &Wells isi, 4 CD5-03 COnOCOPttithps At..1.6 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(fEB) 10/28/2015 10/28/2015 11.75 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole f/13,608'to TD 13,608.0 14,350.0 12:00 23:45 of 14,350'MD 7,399'TVD. ADT=8.39 hrs, ECD 11.44,800 gpm,3420 psi, PU=295 k,S0= 145 k,ROT=200 k, TQ on/off=31 /19.5 k ft-lb SPRs-14,162'md, 19:40 hrs MP#1: 30-540,40-610 MP#2: 30-570,40-610 10/28/2015 10/29/2015 0.25 INTRM1 CASING SRVY P Pump up final survey w/800 gpm @ 14,350.0 14,350.0 23:45 00:00 3420 psi, 140 rpm©32.5 k trq 10/29/2015 10/29/2015 1.50 INTRM1 CASING CIRC P Obtain open reamer parameters. Drop 14,350.0 14,350.0 00:00 01:30 ball&deactivate reamer.Shear @ 2075 stks w/2200 psi. Reamer Open 750 gpm,3180 psi, 4140 trpm Reamer Closed 750 gpm,3390 psi, 4630 trpm 10/29/2015 10/29/2015 10.00 INTRM1 CASING CIRC P Circ hole clean w/800 gpm @ 3700 14,350.0 14,350.0 01:30 11:30 psi, 150 rpm @ 20-22 k trq 10/29/2015 10/29/2015 5.50 INTRM1 CASING CIRC P Wt up as per schedule f/10.4 to 11.1 14,350.0 14,350.0 11:30 17:00 ppg,Maintain 11.5 ppg ECD Initial 775 gpm @ 3470 psi w/150 rpm ©22 k trq Final 378 gpm @ 1230 psi w/50 rpm @17ktrq 10/29/2015 10/29/2015 0.25 INTRM1 CASING OWFF P F/C w/17 rpm(static)SIMOPS-Line 14,350.0 14,350.0 17:00 17:15 up to MPD equipment to Strip OOH 10/29/2015 10/29/2015 0.25 INTRM1 CASING MPDA P Establish circ thru MPD chokes w/350 14,350.0 14,350.0 17:15 17.30 gpm 10/29/2015 10/29/2015 6.00 INTRM1 CASING TRIP P Strip OOH as per MPD schedule 14,350.0 8,808.0 17:30 23:30 f/14,350'to 8,808'.Drag trends continuing to diverge from 9,800'. Work stands several times with no improvement. 10/29/2015 10/30/2015 0.50 INTRM1 CASING TRIP T RIH f/8,808'to 9,189' 8,808.0 9,189.0 23:30 00:00 10/30/2015 10/30/2015 0.50 INTRM1 CASING TRIP T RIH f/9,189'to 9,942' 9,189.0 9,942.0 00:00 00:30 10/30/2015 10/30/2015 2.00 INTRM1 CASING CIRC T Circ hole clean for 1.5 B?U w/400- 9,942.0 9,942.0 00:30 02:30 500 gpm @ 1230-1510 psi,50-120 rpm @ 11.6-13.1 k trq. Hole unloaded drilling beads. 10/30/2015 10/30/2015 0.25 INTRM1 CASING OWFF T F/C w/15 rpm(static) 9,942.0 9,942.0 02:30 02:45 10/30/2015 10/30/2015 0.50 INTRM1 CASING TRIP T Strip OOH f/9,942'to 8,808'as per 9,942.0 8,808.0 02:45 03:15 MPD schedule. 10/30/2015 10/30/2015 6.00 INTRM1 CASING TRIP P Strip OOH f/8,808'to 2,317'as per 8,808.0 2,317.0 03:15 09:15 MPD schedule. 10/30/2015 10/30/2015 0.50 INTRM1 CASING OWFF P F/C(static) 2,317.0 2,317.0 09:15 09:45 10/30/2015 10/30/2015 1.00 INTRM1 CASING TRIP P Strip OOH f/2,317'to 720'as per MPD 2,317.0 720.0 09:45 10:45 schedule. 10/30/2015 10/30/2015 2.50 INTRM1 CASING MPDA P F/C(static)B/D MPD lines&remove 720.0 720.0 10:45 13:15 RCD bearing.Nipple up trip riser. 10/30/2015 10/30/2015 1.00 INTRM1 CASING TRIP P POOH on elevators on TT f/720'to 720.0 139.0 13:15 14:15 10/30/2015 10/30/2015 2.25 INTRM1 CASING BHAH P L/D BHA#2 as per SLB 139.0 0.0 14:15 16:30 Page 9/26 Report Printed: 12/17/2015 - Drilling iterations Summary (with Timelog Depths) _. &Wells CD5-03 ConocoPhitlips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 10/30/2015 10/30/2015 1.00 INTRM1 CASING BHAH P Clean&clear floor of BHA tools& 0.0 0.0 16:30 17:30 equipment. L/D 5"elevators. 10/30/2015 10/30/2015 1.50 INTRM1 CASING RURD P R/U casing tools&equipment. R/U 0.0 0.0 17:30 19:00 Volant.SIMOPS-C/O upper pipe rams to 7 5/8"solid body. 10/30/2015 10/30/2015 0.50 INTRM1 CASING BOPE P M/U test jt&attempt to pull wear ring 0.0 0.0 19:00 19:30 with tugger.No success 10/30/2015 10/30/2015 1.00 INTRM1 CASING BOPE T R/D casing elevators&R/U 5"drilling 0.0 0.0 19:30 20:30 elevators.Attempt to pull on elevators w/22 k(no success).R/D Volant& screw into test joint w/top drive. Puill wear ring free w/30-35 k. 10/30/2015 10/30/2015 2.00 INTRM1 CASING BOPE P Fill stack w/H20.Test annular 0.0 0.0 20:30 22:30 250/2500 psi&chart for 5 min,Test upper rams 250/3500 psi for 5 min (good). R/D testing equip. Pull test jt& set thin wall wear ring. 10/30/2015 10/30/2015 0.50 INTRM1 CASING RURD T R/U Volant&casing elevators 0.0 0.0 22:30 23:00 10/30/2015 10/30/2015 0.75 INTRM1 CASING RURD P R/U power tongs for running 7 5/8" 0.0 0.0 23:00 23:45 casing. R/U spiders&fill up hose. 10/30/2015 10/31/2015 0.25 INTRM1 CASING SFTY P PJSM on running casing 0.0 0.0 23:45 00:00 10/31/2015 10/31/2015 1.50 INTRM1 CASING PUTB P M/U shoe track to 179'(HES float 0.0 179.0 00:00 01:30 shoe,2 jts 7 5/8"39#TN110 casing, HES float collar, 1 jt 7 5/8"39#TN110 casing, HES baffle collar,&1 jt 7 5/8" 39#TN110 casing) 10/31/2015 10/31/2015 0.50 INTRMI CASING PUTB T Attempt to break circ&check floats. 179.0 179.0 01:30 02:00 IBOP on top drive frozen in closed position.Thaw out IBOP w/steam. Break circ check floats.(good) 10/31/2015 10/31/2015 0.50 INTRM1 CASING RURD T B/D top drive.Reconfigure air boot on 179.0 179.0 02:00 02:30 trip nipple. 10/31/2015 11/1/2015 21.50 INTRM1 CASING PUTB P RIH w/7 5/8"casing f/179'to 179.0 11,231.0 02:30 00:00 11,231'(18 total jts of 7 5/8"39# TN110 casing,XO, 155 jts of 7 5/8" 29.7#BTC-M casing, HES stage collar,92 jts of 7 5/8"29.7#BTC-M casing)265 total jts in the hole.SO wt 145 k Page 10/26 Report Printed: 12/17/2015 DriWhig !perations Summary (with Timelog Depths) &Wens CD5-03 conocoPhil lips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/1/2015 11/1/2015 14.50 INTRM1 CASING PUTB P Cont.to RIH with 7-5/8"Intermediate 11,231.0 14,340.0 00:00 14:30 casing from 11,231'to 14,167'. Lost returns at 12,430'and gained 20klbs in down weight.Town support notified and continued to RIH. Started to take weight at 14,166'(Transition from the B3 to B1) momentarily detained. Worked pipe up to 500k cycling do to 50k made 4'. Establish circulation and work up to 2bpm 800psi while working pipe.Start to incur losses and slow pumps to 1.5bpm 530psi.Continue working pipe and downward movement regained and circulation lost/hole packed off.Work pipe to release pack-off and continue to work pipe down pulling up to 400k and slacking off to 50k. Continue to RIH with 7-5/8"casing and pick up and land hanger on depth at14,340'. Only 1'of upward movement obtained while working pipe at original tight spot at 14,167' Land out hanger with 125k down. Blocks 60klbs 11/1/2015 11/1/2015 0.75 INTRM1 CEMENT CIRC P Attempt to re-establish circulation. 14,340.0 14,340.0 14:30 15:15 Start at 1/2bpm with no returns.Pump a total of 25bbls worked rate up to 6bpm at 810psi injection rate. No returns. 11/1/2015 11/1/2015 1.00 INTRM1 CEMENT RURD P Rig down elevators and spiders. 14,340.0 14,340.0 15:15 16:15 Clean and clear rig floor of casing running tools in preparation for cement job. PJSM on cement job 11/1/2015 11/1/2015 3.25 INTRM1 CEMENT CMNT P Dowell pump 1.5 bbls H2O and 14,340.0 14,340.0 16:15 19:30 pressure test lines to 3,500 psi(good), 40.1 bbls 12.0 ppg Mud Push, Drop bypass plug, Pump 87.7 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%excess), Drop top plug. Dowell displace w/10.1 bbls H2O. Rig displace w/640 bbls 11.1 ppg LSND. Bump plug @ 6420 stks,w/3 bpm @ 320 psi.Pressure up to 850 psi&hold for 5 min.Check floats good.CIP @ 19:21 hrs.No reciprocation&no returns. 11/1/2015 11/1/2015 0.50 INTRM1 CEMENT CIRC P Open stage collar @ 6,997'w/3300 6,997.0 6,997.0 19:30 20:00 psi @ 2 bpm.Establish circ w/2bpm @ 350 psi,stage rate to 3 bpm @ 470 psi,stage rate to 4 bpm n@ 520 psi. Lose circulation. 11/1/2015 11/1/2015 1.25 INTRM1 CEMENT CMNT P PJSM on 2nd stage cement. Discuss 6,997.0 6,997.0 20:00 21:15 plan forward with towm.SIMOPS- Clean&clear floor of BHA tools& equipment. Page 11/26 Report Printed: 12/17/2015 !perations Summary (with Timelogepths) Wells CD5-03 Co ocoPhittf Ess Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 11/1/2015 11/2/2015 2.75 INTRM1 CEMENT CMNT P Dowell pump 1.5 bbls H2O and 6,997.0 6,997.0 21:15 00:00 pressure test lines to 3,500 psi(good), 40.1 bbls 12.0 ppg Mud Push,91.2 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%excess), Drop closing plug.Dowell displace w/10.1 bbls H2O.Rig displace w/241 bbls 11.1 ppg LSND w/3 bpm© 170 psi. No returns Total formation losses for past 24 hrs = 1828 bbls 11/2/2015 11/2/2015 0.50 INTRM1 CEMENT CMNT P Rig displace w/69 bbls 11.1 ppg LSND 6,997.0 6,997.0 00:00 00:30 w/3 bpm @ 200 psi.Bump plug 3065 stks.Pressure up to 1100 psi&close stage collar,continue to 2200 psi& hod for 5 min.Bleed off&check floats (good)No returns 11/2/2015 11/2/2015 1.00 INTRM1 CEMENT OWFF P F/C.annulus appear to be dropping, 0.0 0.0 00:30 01:30 floats holding&casing full. Un-sting Volant from landing jt&line up to monitor annulus on nTT.Static losses @ 18 bbls/hr 11/2/2015 11/2/2015 2.25 INTRM1 CEMENT WWSP P Back out landing jt&L/D same. Pull 0.0 0.0 01:30 03:45 wear ring.Set pack off w/5 k wob& RILDS.Test pack off to 5000 psi (good) 11/2/2015 11/2/2015 1.50 INTRM1 CEMENT RURD P R/D Volant casing tools&equipment. 0.0 0.0 03:45 05:15 R/U 5"elevators. 11/2/2015 11/2/2015 0.75 INTRM1 CEMENT WWWH P M/U stack washer&flush stack. 0.0 0.0 05:15 06:00 11/2/2015 11/2/2015 1.50 INTRM1 CEMENT SLPC P Slip&cut 60'drill line.Re-calibrate 0.0 0.0 06:00 07:30 block height. 11/2/2015 11/2/2015 0.50 INTRM1 CEMENT SVRG P Service rig,top drive&blocks 0.0 0.0 07:30 08:00 11/2/2015 11/2/2015 1.25 INTRM1 CEMENT MPDA P Strip off of DP 2 MPD bearings used 0.0 0.0 08:00 09:15 to drill intermediate section.Clear floor of MPD tools&equip. 11/2/2015 11/3/2015 14.75 INTRM1 CEMENT PULD P L/D 372 jts 5"DP from derrick via 90' 0.0 0.0 09:15 00:00 mouse hole.(SIMOPS @ 11:00 hrs Annular disposal injectivity test,water flush&freeze protect on 10 3/4"X 7 5/8"annulus) 11/3/2015 11/3/2015 0.75 INTRM1 CEMENT PULD P L/D 18jts 5"DP from derrick via 90' 0.0 0.0 00:00 00:45 mouse hole 11/3/2015 11/3/2015 2.25 INTRM1 WHDBOP RURD P L/D 5"handling equipment. Bring to rig 0.0 0.0 00:45 03:00 floor XT39 FOSV&Dart valves. Prep for BOPE test,. FMC set upper test plug. Fill stack w/H20&R/U to test BOPE. Page 12/26 Report Printed: 12/17/2015 t�rtl tperations Summary (with Timelog 6epths) :.'• &Weds CD5-03 C onocoPhill ps Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2015 11/3/2015 7.00 INTRMI WHDBOP BOPE P BOPE Test:Test with 3,4&4 1/2" 0.0 0.0 03:00 10:00 test joints,Test Annular to 250/2,500 psi for 10 min,Test choke valves#1 - 14 and needle valve to 250/3,500 psi for 10 min.HCR Choke and Kill,4" Demco,4"FOSV,dart&needle valves,HCR choke&kill,3 1/2"X 6" upper&lower VBR's,&blind rams to 250/3500 psi for 10 min.-good. Koomey test; IP=3,100 psi, manifold press after close=1,500 psi,200 psi recovery 36 sec,full recovery 222 sec, N2-4 bottle average=1990 psi. Tested gas alarms.Draw down on man&super choke to 1,100 psi. - Test witnessing waived by Bob Noble of the AOGCC. 11/3/2015 11/3/2015 0.50 INTRM1 WHDBOP RURD P B/D choke manifold&kill lines. R/D 0.0 0.0 10:00 10:30 testing equipment.Pull upper test plug. Install split bushings. 11/3/2015 11/3/2015 4.00 INTRM1 CEMENT RURD P CIO saver sub to XT 39.C/O elevators 0.0 0.0 10:30 14:30 to 4". Install skate roller. Install 7.0625 ID wear ring.Adjust air boot on trip nipple.SIMOPS-Bring BHA tools& equip to rig floor. 11/3/2015 11/3/2015 2.75 INTRM1 CEMENT BHAH P M/U BHA#3 as per SLB to 371' 0.0 371.0 14:30 17:15 11/3/2015 11/4/2015 6.75 INTRM1 CEMENT PULD P RIH w/BHA#3 while single in hole 371.0 5,185.0 17:15 00:00 with 4"DP from pipe shed f/371'to 5,185' 11/4/2015 11/4/2015 2.50 INTRM1 CEMENT PULD P RIH while P/U 4"DP f/5,185'to 6,810'. 5,185.0 6,810.0 00:00 02:30 Fill pipe every 20 stands 11/4/2015 11/4/2015 0.75 INTRM1 CEMENT PRTS P R/U testing equip.Test casing to 1000 6,810.0 6,810.0 02:30 03:15 psi for 10 min.(good). B/D&R/D testing equip. 11/4/2015 11/4/2015 1.00 INTRM1 CEMENT COCF P W&R f/6,810'to stage collar 6,981' 6,810.0 6,981.0 03:15 04:15 w/190-220 gpm @ 1000-1220 psi, 40-60 rpm @ 5.5-6 k trq. 11/4/2015 11/4/2015 2.25 INTRM1 CEMENT DRLG P Drill stage collar f/6,981'to 6,984' 6,981.0 6,984.0 04:15 06:30 w/130-200 gpm @ 490-1200 psi,25 rpm @ 5.5-6.5 k trq,5-15 k wob 11/4/2015 11/4/2015 1.25 INTRM1 CEMENT COCF P W&R f/6,984'to 7,286'w/200 gpm @ 6,984.0 7,286.0 06:30 07:45 1090 psi,30 rpm @ 3-4 k trq. 11/4/2015 11/4/2015 0.50 INTRM1 CEMENT PRTS P R/U testing equip.Test casing to 1500 7,286.0 7,286.0 07:45 08:15 psi for 5 min. (good). B/D&R/D testing equip. 11/4/2015 11/4/2015 8.50 INTRM1 CEMENT PULD P RIH while P/U 4"DP f/7,286'to 7,286.0 13,533.0 08:15 16:45 13,533'. Fill pipe every 20 stands 11/4/2015 11/4/2015 1.00 INTRM1 CEMENT COCF P W&R f/13,533'to 13,730'w/200 gpm 13,533.0 13,730.0 16:45 17:45 @ 1090 psi,30 rpm @ 3-4 k trq. 11/4/2015 11/4/2015 1.50 INTRM1 CEMENT PULD P RIH while P/U 4"DP f/13,730'to 13,730.0 14,013.0 17:45 19:15 14,013'. 11/4/2015 11/4/2015 1.25 INTRM1 CEMENT PRTS P R/U testing equip.Test casing to 3500 14,013.0 14,013.0 19:15 20:30 psi for 30 min.(good). B/D&R/D testing equip. Page 13/26 Report Printed: 12/17/2015 • Drilliir' lig Operations Summary (with Timelog Depths) : _, Wens CD5-03 ConocoPhillips A,.t:i^:1kh Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2015 11/5/2015 3.50 INTRM1 CEMENT DRLG P Tag TOC @ 14,055'. Drill cement& 14,013.0 14,287.0 20:30 00:00 shoe track f/14,055'to 14,287'w/150- 225 gpm @ 1300-2380 psi,30 rpm @ 13.5 -18 k trq(tag baffle collar @ 14,204'&float collar 14,248'as per tally) 11/5/2015 11/5/2015 1.00 INTRM1 CEMENT DRLG P Drill out shoe track&10'rat hole 14,287.0 14,350.0 00:00 01:00 (/14,287'to 14,350'w/250 gpm @ 2600 psi,30 rpm @ 14.5 k trq.(Shoe on depth as per tally @ 14,340' 11/5/2015 11/5/2015 0.50 INTRM1 CEMENT DDRL P Drill 20'new formation f/14,350'to 14,350.0 14,370.0 01:00 01:30 14,370'MD/7400'TVD,ADT.26, ECD 12.22 ppg,PU wt 275 k,SO wt 125 k, ROT wt 170 k, 100 rpm,Trq on/off 17.5/14.5 k ft lbs,wob 10-15 11/5/2015 11/5/2015 0.25 INTRM1 CEMENT BKRM P BROOH f/14,370'to 14,287'w/250 14,370.0 14,287.0 01:30 01:45 gpm @ 2760 psi, 100 rpm @ 15.5 k trq(No rotary across shoe) 11/5/2015 11/5/2015 1.25 INTRM1 CEMENT CIRC P Circ B/U w/250 gpm @ 2760 psi,50 14,287.0 14,287.0 01:45 03:00 rpm @ 15.5 k trq 11/5/2015 11/5/2015 1.00 INTRM1 CEMENT FIT P R/U testing equip&LOT to 12.5 ppg 14,287.0 14,287.0 03:00 04:00 @ 540 psi, B/D&R/D testing equip. 11/5/2015 11/5/2015 1.00 PROD1 DRILL MPDA P Remove trip nipple&install 4"MPD 14,287.0 14,287.0 04:00 05:00 bearing. 11/5/2015 11/5/2015 0.50 PROD1 DRILL REAM P W&R 14,287'to 14,370'w/220-200 14,287.0 14,370.0 05:00 05:30 gpm @ 2530-2080 psi&various rpm to breakin mpd bearing. 11/5/2015 11/5/2015 0.25 PROD1 DRILL DDRL P Drill stand down f/14,370'to 14,383'. 14,370.0 14,383.0 05:30 05:45 SIMOPS-PJSM on displacing to Flo Pro 11/5/2015 11/5/2015 2.00 PROD1 DRILL DISP P Displace from 11.1 ppg LSND to new 14,383.0 14,383.0 05:45 07:45 10.1 ppg Flo Pro w/250 gpm @ 2700 psi,80 rpm @ 12.5 k trq 11/5/2015 11/5/2015 0.25 PROD1 DRILL CIRC P Pull inside casing&obtain SPR's 14,383.0 14,319.0 07:45 08:00 11/5/2015 11/5/2015 1.00 PROD1 DRILL OWFF P OWFF,flow observed.Close MPD 14,319.0 14,319.0 08:00 09:00 chokes.Observe 137 psi in 13 min. SIMOPS-Discuss plan forward w/drilling&engineering team. Decision made to reduce mud wt to 9.9 ppg&resume drilling ahead. 11/5/2015 11/5/2015 3.00 PROD1 DRILL DDRL P Drill ahead(/14,370'to 14,592'MD/ 14,319.0 14,592.0 09:00 12:00 7399'TVD,ADT 2.10,ECD 11.36 ppg, 240 gpm,2630 psi,PU wt 280 k,SO wt 135 k, ROT wt 170 k, 150 rpm,Trq on/off 15.8/11 k ft lbs,wob 9-12 11/5/2015 11/6/2015 12.00 PROD1 DRILL DDRL P Drill ahead f/14,592'to 15,813'MD/ 14,592.0 15,813.0 12:00 00:00 7391'TVD,ADT 9.01, ECD 11.36 ppg, 260 gpm,2680 psi,PU wt 225 k,SO wt 130 k, ROT wt 169 k, 150 rpm,Trq on/off 17/10.5 k ft lbs,wob 9-14, Closing MPD chokes on connections &monitoring psi Page 14/26 Report Printed: 12/17/2015 • Operations Summary (with Timelog•pths) tkWei CD5-03 ConocoPhillips , Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2015 11/6/2015 3.75 PROD1 DRILL DDRL P Drill ahead f/15,813'to 16,204'MD/ 15,813.0 16,204.0 00:00 03:45 7396'TVD,ADT 2.81.Crossed fault f/16,095'to 16,120'.Observed formation losses, Pump pressure decreased f/2860 to 2760, ECD decreased f/11.4 to 11.15 ppg,and saw a 25%decrease in flow out. Reduced drilling parameters from 250 gpm to 220 gpm&reduced rop f/150' per hr to 100 fUhr. Losses appeared to be<30 bbls/hr. Made connection @ 16,195'and resumed drilling ahead while adding Dyna Red fine&med to active to control losses.After only drill 9'f/16,195'to 16,204'loss rate increased to 120 bbls per/hr.Stopped drilling. 11/6/2015 11/6/2015 0.50 PROD1 DRILL BKRM T Established circulation w/50 gpm @ 16,204.0 16,195.0 03:45 04:15 600 psi,25 rpm @ 10.5 k trq with minimal losses&BROOH f/16,204'to 16,195'(Performed differential sticking test prior to making connection) 11/6/2015 11/6/2015 4.50 PROD1 DRILL CIRC T Establish circulation w/50 gpm and 16,195.0 16,195.0 04:15 08:45 partial losses. Increase to 100 gpm w/30 bbl/hr loss rate. Mix and pump 32 bbl LCM sweep(5 ppb Dyna Red Fine&5 ppb Dyna Red Med).Once sweep outside bit increase flow rate to 150 gpm w/60 bbl/hr loss rate and dynamically squeeze pill into fault. Cont.to circ w/100 gpm while build another 33 bbl LCM sweep(5 ppb Dyna Red Fine,5 ppb Dyna Red Med, 10 ppb Nut Plug Fine,&5 ppb Nut Plug Med for 25 ppb total) Pump 2nd LCM sweep w/100 gpm. Once sweep outside bit increase flow rate to 200 gpm and dynamically squeeze pill into fault. Losses slowed down to 30 bb/hr with second LCM sweep @ 200 gpm.Decision made to resume drilling ahead 11/6/2015 11/6/2015 3.25 PROD1 DRILL DDRL P Drill ahead(/16,204'to 16,420'MD/ 16,204.0 16,420.0 08:45 12:00 7396'TVD,ADT 2.71, ECD 11.07 ppg, 205 gpm,2070 psi,PU wt 220 k,SO wt 123 k, ROT wt 167 k, 120 rpm,Trq on/off 15.4/11 k ft lbs,wob 10-12, Closing MPD chokes on connections &monitoring psi. Loss rate+/-40 bbls/hr. 11/6/2015 11/7/2015 12.00 PROD1 DRILL DDRL P Drill ahead f/16,420'to 17,312'MD/ 16,420.0 17,312.0 12:00 00:00 7384'TVD,ADT 9.59, ECD 11.06 ppg, 220 gpm,2330 psi, PU wt 225 k,SO wt 124 k,ROT wt 169 k, 150 rpm,Trq on/off 15/10.5 k ft lbs,wob 9-14, Closing MPD chokes on connections &monitoring psi. Reduced mud wt f/9.8ppg to 9.4 ppg. Loss rate 15 bbs/hr. Lost 404 total bbls past 24 hrs. Page 15/26 Report Printed: 12/17/2015 Drwi1 HMI operations Summary (with Timelog•pths) &Wells CD5-03 Conoco' Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/7/2015 11/7/2015 12.00 PROD1 DRILL DDRL P Drill ahead f/17,312'to 18,251'MD/ 17,312.0 18,251.0 00:00 12:00 7378'TVD,ADT 9.52 hrs, ECD 11.2 ppg,270 gpm,3110 psi, PU wt 225 k, SO wt 132 k, ROT wt 170 k, 120 rpm, Trq on/off 16.5/11 k ft lbs,wob 8-10, Closing MPD chokes on connections &monitoring psi.Loss rate+/-10 bbs/hr. 11/7/2015 11/7/2015 6.50 PROD1 DRILL DDRL P Drill ahead f/18,251'to 18,460'MD/ 18,251.0 18,460.0 12:00 18:30 7384'TVD,ADT 5.99 hrs,Time drill to aid in rotary steerable tool to build inclination,no success. 11/7/2015 11/7/2015 1.00 PROD1 DRILL CIRC T Rotary steerable tool appears to be 18,460.0 18,460.0 18:30 19:30 responding to downlink commands, but mechanically not building inc. Circulate w/265 gpm @ 3100 psi, 120 rpm @ 12.5 trq. Discuss plan forward options with drilling,engineering,& geological team.Decision made to drill ahead and exit the Alpine A and see if tool will build inclination. 11/7/2015 11/7/2015 3.75 PROD1 DRILL DDRL P Drill ahead f/18,460'to 18,768'MD/ 18,460.0 18,768.0 19:30 23:15 7398'TVD,ADT 3.0 hrs,ECD 11.31 ppg,260 gpm,3040 psi,PU wt 227 k, SO wt 118 k,ROT wt 163 k, 120 rpm, Trq on/off 13.5/10 k ft lbs,wob 5-10, Closing MPD chokes on connections &monitoring psi. Loss rate+/-10 bbs/hr.(Exited the bottom of the Alpine A @+/-18,590',tool did not build angle,decision made to POOH for new BHA)18'TVD below the pay 11/7/2015 11/8/2015 0.75 PROD1 DRILL CIRC T Pump up final survey.SPR's.Circ B/U 18,768.0 18,768.0 23:15 00:00 w/260 gpm @ 2980 psi, 120 rpm @ 11.5 k trq. 11.2 ppg ECD Lost 278 bbls total in past 24 hrs. 11/8/2015 11/8/2015 1.00 PROD1 DRILL CIRC T Circ B/U w/260 gpm @ 2980 psi, 120 18,768.0 18,768.0 00:00 01:00 rpm @ 11.5 k trq. 11.0 ppg ECD 11/8/2015 11/8/2015 0.25 PROD1 DRILL RURD T B/D top drive. R/U to perform draw 18,768.0 18,768.0 01:00 01:15 down 11/8/2015 11/8/2015 0.50 PROD1 DRILL OWFF T Perform formation draw down test. 18,768.0 18,768.0 01:15 01:45 Pressure build from 5 to 17 psi in 10 min. Bleed 5.9 gallon in 10 min.Shut in and 0 psi in 10 min 11/8/2015 11/8/2015 15.00 PROD1 DRILL CIRC T Circ hole clean w/260 gpm @ 2980 18,768.0 18,768.0 01:45 16:45 psi, 120 rpm @ 10-11 k trq. 11.0 ppg ECD.Pump 34 bbl LCM sweep.Circ and wait on 9.5 ppg brine to be mobilized to rig. 11/8/2015 11/8/2015 2.75 PROD1 DRILL DISP T Pump 37 bbl spacer&displace to 9.5 18,768.0 18,768.0 16:45 19:30 ppg viscosified brine w/260 gpm @ 2830-2270 psi, 120 rpm @ 6.5-9 k trq. 11/8/2015 11/8/2015 0.25 PROD1 DRILL OWFF T B/D top drive&F/C w/10 rpm(static) 18,768.0 18,768.0 19:30 19:45 11/8/2015 11/8/2015 0.25 PROD1 DRILL MPDA T Line up MPD equipment to strip OOH. 18,768.0 18,768.0 19:45 20:00 Page 16/26 Report Printed: 12/17/2015 : Drilling Operations Summary (with Timelog•pths) Wens CD5-03 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/8/2015 11/9/2015 4.00 PROD1 DRILL TRIP T Strip OOH f/18768'to 15,138'as per 18,768.0 15,138.0 20:00 00:00 MPD schedule,holding 20 psi in slips &160 psi while pulling. Lost 167 bbls past 24 hrs. 11/9/2015 11/9/2015 10.25 PROD1 DRILL TRIP T Strip OOH f/15,138'to 1,504'as per 15,138.0 1,504.0 00:00 10:15 MPD schedule,holding 20 psi in slips &160-90 psi while pulling. 11/9/2015 11/9/2015 0.25 PROD1 DRILL OWFF T F/C(static)SIPMOPS-PJSM on 1,504.0 1,504.0 10:15 10:30 MPD bearing&trip nipple 11/9/2015 11/9/2015 1.50 PROD1 DRILL MPDA T B/D MPD equip.Pull MPD bearing& 1,504.0 1,504.0 10:30 12:00 install trip nipple.Hook up hole fill lines&bleeder lines. 11/9/2015 11/9/2015 1.00 PROW DRILL SLPC T Slip&cut 60'drill line 1,504.0 1,504.0 12:00 13:00 11/9/2015 11/9/2015 1.00 PROD1 DRILL SVRG T Service rig.Adjust brakes&equalizer 1,504.0 1,504.0 13:00 14:00 bar.Service top drive&draw works. 11/9/2015 11/9/2015 1.00 PROW DRILL TRIP T POOH f/1,504'to 371' 1,504.0 371.0 14:00 15:00 11/9/2015 11/9/2015 2.00 PROW DRILL BHAH T Rack back HWDP,Jars,&NMFC. L/D 371.0 0.0 15:00 17:00 BHA as per SLB 11/9/2015 11/9/2015 0.50 PROD1 DRILL BHAH T Clean&clear floor of BHA tools& 0.0 0.0 17:00 17:30 equip. 11/9/2015 11/9/2015 0.75 PROD1 WHDBOP RURD T P/U test jt&pull wear ring. Drain 0.0 0.0 17:30 18:15 stack.Set test plug.R/U to test BOPE. Fill lines w/H2O 11/9/2015 11/10/2015 5.75 PROD1 WHDBOP BOPE T BOPE Test:Test with 3 1/2 test joint, 0.0 0.0 18:15 00:00 Test Annular to 250/2,500 psi for 5 min,Test choke valves#1 -14 and needle valve to 250/3,500 psi for 5 min.HCR Choke and Kill,4"Demco, 4"FOSV,dart&needle valves,auto& manual IBOP, HCR choke&kill,3 1/2" X 6"upper&lower VBR's, to 250/3500 psi for 5 min.-good.Test witnessing waived by Jeff Jones of the AOGCC. Lost 68 bbls total past 24 hrs 11/10/2015 11/10/2015 1.50 PROD1 WHDBOP BOPE T Test BOPE w/4 1/2"test jt.3 1/2"X 6" 0.0 0.0 00:00 01:30 upper&lower VBR's,&blind rams to 250/3500 psi for 5 min.-good. Koomey test; IP=3,000 psi,manifold press after close=1,450 psi,200 psi recovery 35 sec,full recovery 220 sec, N2-4 bottle average=2000 psi. Draw down on man&super choke to 1,100 psi.-Test witnessing waived by Jeff Jones of the AOGCC. Lost 10 bbls while testing. 11/10/2015 11/10/2015 0.75 PROD1 WHDBOP RURD T B/D lines. Pull test plug and set wear 0.0 0.0 01:30 02:15 ring. R/D testing equipment. 11/10/2015 11/10/2015 1.50 PROD1 DRILL BHAH T PJSM.Make up BHA#4 as per SLB 0.0 371.0 02:15 03:45 11/10/2015 11/10/2015 0.75 PROD1 DRILL TRIP T RIH to 1,504'. PU=S0=85K lb. 371.0 1,504.0 03:45 04:30 11/10/2015 11/10/2015 0.50 PROD1 DRILL DHEQ T Shallow pulse test MWD with 240 1,504.0 1,504.0 04:30 05:00 gpm, 1.050 psi. Blow down TD. Page 17/26 Report Printed: 12/17/2015 • . Minims; operations Summary (with Timelog Depths) { &Wells CD5-03 ConocoPhil lips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/10/2015 11/10/2015 8.50 PROD1 DRILL TRIP T RIH from 1,504'-14287,filling pipe 1,504.0 14,287.0 05:00 13:30 every 20 stds. 11/10/2015 11/10/2015 1.00 PROD1 DRILL MPDA T PJSM. Drain Trip Nipple,blow down 14,287.0 14,287.0 13:30 14:30 Hole Fill line,pull Trip Nipple and install MPD element 11/10/2015 11/10/2015 2.25 PROD1 DRILL TRIP T RIH from 14,287'-17,151',filling pipe 14,287.0 17,151.0 14:30 16.45 every 20 stds. 11/10/2015 11/10/2015 1.50 PROD1 DRILL REAM T Wash down from 17,151'to 17,207' 17,151.0 17,207.0 16:45 18:15 with 250 gpm,2,1710 psi. 120 rpm, 7.5K TQ.Obtain ABI map from 17,207 to 17,175'and with 250 gpm,2,100 psi, 5-10 rpm,6K TQ. 11/10/2015 11/10/2015 3.25 PROD1 DRILL DDRL T Trough from 17,175' 17,145',while 17,175.0 17,175.0 18:15 21:30 displacing hole from 9.5 ppg viscosified brine to 9.3 ppg Flo-Pro mud with 250 gpm, 1,820-2,560 psi, 120 rpm and 6K TQ. 11/10/2015 11/11/2015 2.50 PROD1 DRILL DDRL T Time drill at 1.0-0.5 ft/hr from 17,175' 17,175.0 17,175.8 21:30 00:00 to 17,175.75'. Total losses for 24 hours=26 bbl ADT: 1.6 hr TVD-7,385' 11/11/2015 11/11/2015 12.00 PROD1 DRILL DDRL T Time drill at 0.2-1.0 ft/hr from 17,175.8 17,179.5 00:00 12:00 17,175.75'to 17,179.5'. Total losses for 24 hours=26 bbl ADT: 10.8 hr TVD-7,385' 11/11/2015 11/11/2015 9.00 PROD1 DRILL DDRL T Time drill at 0.2-1.0 ft/hr from 17,179.5 17,197.0 12:00 21:00 17,179.5'to 17,197'. PU=220K,S0= 135K,ROT= 175K Ib,TQ=4.0-8.5K ft-lb Total losses for 24 hours=26 bbl ADT:8.57 hr TVD-7,385' 11/11/2015 11/11/2015 0.25 PROD1 DRILL OWFF T Flo-chk-static.(rotate at 5 rpm,5K 17,197.0 17,197.0 21:00 21:15 TQ) 11/11/2015 11/11/2015 2.00 PROD1 DRILL PMPO T Pump-OOH from 17,197'to 16,400' 17,197.0 16,400.0 21:15 23:15 with 210 gpm, 1,750 psi 11/11/2015 11/12/2015 0.75 PROD1 DRILL DDRL T Trench from 16,377'to 16,406'with 16,400.0 16,406.0 23:15 00:00 250 gpm,2,550 psi,7K TQ. SPRs-16,447'md,23:20 hrs MP#1: 15-700,25-920 MP#2: 15-660,25-890 11/12/2015 11/12/2015 6.00 PROD1 DRILL DDRL T Trench from 16,377'to 16,406'with 16,400.0 16,406.0 00:00 06:00 250 gpm,2,560 psi,6.5-7.5K TQ. 11/12/2015 11/12/2015 7.25 PROD1 DRILL DDRL T Time drill at 1'/hr from 16,406'to 16,406.0 16,419.0 06:00 13:15 16,408',2'/hr from 16,408'to 16,416', 4'/hr from 16,416'to 16,419'. PU= 225K,SO= 135K, ROT= 165K Ib,TQ= 4.0-8.5K ft-lb ADT:5.92 hr TVD-7,395' 11/12/2015 11/12/2015 0.25 PROD1 DRILL TRIP T POOH to top of trench at 16,377'. 16,419.0 16,419.0 13:15 13:30 Slide back down thru trench to 16,419' and with no ledge encountered.(well not sidetracked). Page 18/26 Report Printed: 12/17/2015 Iterations Summary (with Timelog Depths) • Dri &Wens CD5-03 Phiirips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'.. 11/12/2015 11/12/2015 1.75 PROD1 DRILL TRIP T Confer with Drilling staff on plan 16,419.0 18,676.0 13:30 15:15 forward. Continue to RIH from 16,419'to 18,676'. 11/12/2015 11/12/2015 1.00 PROD1 DRILL DLOG T Continue to RIH to TD and MAD pass 18,676.0 18,768.0 15:15 16:15 from 18,676'to 18,768'for log correlation with 250 gpm,2,850 psi, 140 rpm and 11K TQ. 11/12/2015 11/12/2015 1.75 PROD1 DRILL DDRL P Drill 6-1/2"hole from 18,768' to 18,768.0 18,863.0 16:15 18:00 18,863'. ADT= 1.53 hrs,TVD= 7,400'. SPRs-18,863'md,21:00 hrs MP#1: 15-820,25-1120 MP#2: 15-840,40-1060 11/12/2015 11/12/2015 3.00 PROD1 DRILL SRVY T Trouble shoot MWD survey tool 18,676.0 18,768.0 18:00 21:00 (azimuth error,inclination-ok). Perform quadrant survey checks 2 times(8 surveys).Circ at 250 gpm, 2,850 psi, 140 rpm and reciprocate pipe due to sticky formation conditions (max PU=275K,min S0=75K). 11/12/2015 11/13/2015 3.00 PROD1 DRILL DDRL P Confirm MWD tools working correctly. 18,863.0 19,039.0 21:00 00:00 Drill 6-1/2"hole from 18,863' to 19.039'. ADT=3.26 hrs,TVD= 7,389'. PU=227K,SO= 130K, ROT= 172K,TQ on/off= 19.0K/11.5K ft-lb, ECD-11.21 ppg ADT:4.79 hr TVD-7,389' Total losses for 24 hours=60 bbl 11/13/2015 11/13/2015 12.00 PROD1 DRILL DDRL P Drill 6-1/2"hole from 19,039' to 19,039.0 20,191.0 00:00 12:00 20,191'. ADT=9.67 hrs,TVD= 7,338'. PU=225K,S0= 122K,ROT= 165K,TQ on/off=19.0/13.5K SPRs-20,006'md,09:50 hrs MP#1: 15-880,25-1140 MP#2: 15-890,40-1140 11/13/2015 11/13/2015 9.25 PROD1 DRILL DDRL P Drill 6-1/2"hole from 20,191' to 20,191.0 20,999.0 12:00 21:15 20,999'. ADT=6.96 hrs,TVD= 7,332'. PU=230K,SO=115K,ROT= 163K,TQ on/off=18.5/12.5K SPRs-20,999'md,21:15 hrs MP#1: 15-850,25-1150 MP#2: 15-880,40-1100 Note: No increase seen in choke pressure at connections over interval drilled. 11/13/2015 11/13/2015 2.25 PROD1 CASING CIRC P Survey hole at TD. CBU lx at 257 20,999.0 20,990.0 21:15 23:30 gpm,3,170 psi, 140 rpm, 17.1K TQ while reciprocating pipe 30'. Page 19/26 Report Printed: 12/17/2015 .4.„' 0 � Operations Summary (with TimelogDepths) Drilling , Wells CD5-03 ConocoPhillips Maaka u Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/13/2015 11/14/2015 0.50 PROD1 CASING OWFF P Allow well to breathe for 5 minutes 20,999.0 20,990.0 23:30 00:00 while blowing down TD and lines,shut -in annulus with MPD and monitor shut-in pressure for 6 minutes. Initial= 4 psi,final=12 psi. Open MPD chokes, rotate at 5 rpm and flow chk for 15 min.-static. 11/14/2015 11/14/2015 1.25 PROD1 CASING CIRC P CBU with 260 gpm,3,150 psi, 140 20,999.0 20,999.0 00:00 01:15 rpm and 18K TQ while reciprocating drill string 30'. 11/14/2015 11/14/2015 0.25 PROD1 CASING CIRC P POOH to 20,928',rack back one 20,999.0 20,928.0 01:15 01:30 stand,blow down TD, RU head pin and 1502 circulating equip. 11/14/2015 11/14/2015 0.75 PROD1 CASING CIRC P Continue to CBU with 260 gpm,3,150 20,928.0 20,999.0 01:30 02:15 psi and reciprocating pipe every 5-10 min with max pull=265K.SIMOPs: lubricate rig and change out wash pipe on Top Drive. RD head pin,screw in with TD and continue to CBU. 11/14/2015 11/14/2015 5.00 PROD1 CASING CIRC P Continue to CBU with 260 gpm,3,150 20,999.0 20,999.0 02:15 07:15 psi, 140 rpm and 18K TQ while reciprocating drill string 30'. PJSM for displacement. 11/14/2015 11/14/2015 2.25 PROD1 CASING DISP P Displace 9.3 ppg Flo-Pro mud from 20,999.0 20,999.0 07:15 09:30 well with Hi-Vis spacer followed by 806 bbl of 9.5 ppg NaCI/NaBr brine with 2.5%MI-776 lubricant at 260 gpm,3,320-2,600 psi, 140 rpm and 18.0-11.5K TQ. 11/14/2015 11/14/2015 1.00 PROD1 CASING CIRC P C&C brine with 260 gpm,2,600 psi, 20,999.0 20,999.0 09:30 10:30 140 rpm and 11K TQ until fluid properties were uniform. PU=235K, SO= 135K and ROT= 180K(while pumping 2 bpm). SPRs-20,999'md, 10:00 hrs MP#1: 15-340,25-590 MP#2: 15-340,25-590 11/14/2015 11/14/2015 0.25 PROD1 CASING OWFF P Flo-chk with 5 rpm 10K TQ-static 20,999.0 20,999.0 10:30 10:45 (fluid level dropping in annulus). 11/14/2015 11/14/2015 1.25 PROD1 CASING TRIP P Strip-OOH from 20,999'to 20,006' 20,999.0 20,006.0 10:45 12:00 following trip schedule and holding back pressure with MPD(180 psi tripping,20 psi at connections). 11/14/2015 11/14/2015 1.75 PROD1 CASING TRIP P Continue to Strip-OOH from 20,006'to 20,006.0 18,672.0 12:00 13:45 18,672'following trip schedule and holding back pressure with MPD(180 psi tripping,20 psi at connections). Overpull 35K lb at 19,371'.Work tight spot and continue to SOOH to 19,067' and overpull 35K lb.Work tight spot and continue to SOOH to 18,576'and with continuous overpull of 35K lb. (vertical low point in well path"sump" at 18,880'md). Confer with town and decide to RIH thru sump and circulate out possible cuttings beds from low spot. Page 20/26 Report Printed: 12/17/2015 • • Operations Summary (with Timelog Depths) :f _,t Drilling 1s CD5-03 Coro iithps . Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/14/2015 11/14/2015 0.50 PROD1 CASING TRIP T RIH from 18,672'to 18,804'stacking 18,672.0 18,804.0 13:45 14:15 out with 40K lb. PU with 25K overpull. MU TD and blow down lines. 11/14/2015 11/14/2015 2.00 PROD1 CASING REAM T Wash and ream from 18,804'to 18,804.0 19,434.0 14:15 16:15 19,434'with 240 gpm,2,120 psi, 100 rpm and 8K TQ. 11/14/2015 11/14/2015 1.00 PROD1 CASING CIRC T CBU with 260 gpm,2,320 psi, 140 19,434.0 19,434.0 16:15 17:15 rpm and 8.3K TQ. 11/14/2015 11/14/2015 0.50 PROD1 CASING OWFF T Flo-chk. Close MPD choke to watch 19,434.0 19,434.0 17:15 17:45 pressure build up while rotating at 5 rpm,7.3K TQ.Observed annulus pressure dropping due to annulus fluid drop(vacuum). Blow down TD and prep to continue SOOH. 11/14/2015 11/14/2015 5.25 PROD1 CASING TRIP P Strip-OOH from 19,434'to 14,287' 19,434.0 14,287.0 17:45 23:00 following trip schedule and holding back pressure with MPD(180 psi tripping,20 psi at connections). Note:passed thru tight spots with only 5-10K lb of drag. 11/14/2015 11/15/2015 1.00 PROD1 CASING CIRC P Circ 35 bbl Hi-VIS sweep inside 7-5/8" 14,287.0 14,335.0 23:00 00:00 casing shoe with 260 gpm, 1,760 psi, 90 rpm and 5.7K TQ.with an increase of fine grained sand returns. Total losses for 24 hr=79 bbl(3.3 bbl/hr average) 11/15/2015 11/15/2015 1.00 PROD1 CASING CIRC P Continue to circ 35 bbl Hi-VIS sweep 14,335.0 14,335.0 00:00 01:00 inside 7-5/8"casing shoe with 260 gpm, 1,760 psi,90 rpm and 5.7K TQ. with an increase of fine grained sand returns. PU=260K,SO=165K, ROT= 185K lb. PJSM for change out of leaking MPD element. 11/15/2015 11/15/2015 0.75 PROD1 CASING CIRC P Continue to C&C mud w/o rotating. 14,335.0 14,335.0 01:00 01:45 Pump dry job. Blow down TD. 11/15/2015 11/15/2015 1.00 PROD1 CASING MPDA P Change out MPD element and break 14,335.0 14,335.0 01:45 02:45 in with 25 rpm,5K TQ,without pumping. SIMOPs:Flow-chk-static (fluid level dropping). 11/15/2015 11/15/2015 4.75 PROD1 CASING TRIP P Strip-OOH from 19,434'to 14,287' 14,335.0 6,047.0 02:45 07:30 following trip schedule and holding back pressure with MPD(160-100 psi tripping,20 psi at connections). PU= 132K,S0= 110K lb. 11/15/2015 11/15/2015 4.25 PROD1 CASING PULD P Continue to Strip-OOH from 6,047'to 6,047.0 1,409.0 07:30 11:45 1,409',laying down 49 stds of 4"DP and following trip schedule,holding back pressure with MPD(100-80 psi tripping,20 psi at connections). 11/15/2015 11/15/2015 0.25 PROD1 CASING OWFF P Flo-chk-static 1,409.0 1,409.0 11:45 12:00 11/15/2015 11/15/2015 0.50 PROD1 CASING MPDA P Flush MPD equip with water at 3-4 1,409.0 1,409.0 12:00 12:30 bpm, 140-230 psi and blow down. 11/15/2015 11/15/2015 1.00 PROD1 CASING MPDA P Pull MPD element from RCD and 1,409.0 1,409.0 12:30 13:30 install Trip nipple. 11/15/2015 11/15/2015 1.25 PROD1 CASING PULD P POOH from 1,409'to 371',laying 1,409.0 371.0 13:30 14:45 down 11 stds of 4"DP. Page 21/26 Report Printed: 12/17/2015 • Drilling Operations Summary (with Timelog Depths) CD5-03 ConoC0Phillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/15/2015 11/15/2015 0.25 PROD1 CASING SFTY P PJSM on laying down BHA. 371.0 371.0 14:45 15:00 11/15/2015 11/15/2015 1.00 PROD1 CASING BHAH P LDBHA#4 371.0 0.0 15:00 16:00 Calc/Actual fill for SOOH= 129/186 bbl 11/15/2015 11/15/2015 1.00 COMPZN CASING RURD P Clear and clean rig floor, RU casing 0.0 0.0 16:00 17:00 equip. 11/15/2015 11/15/2015 0.50 COMPZN CASING SVRG P Service TD, Iron Roughneck, 0.0 0.0 17:00 17:30 drawworks and pipe skate. 11/15/2015 11/15/2015 0.50 COMPZN CASING SFTY P PJSM for running 4-1/2"liner 0.0 0.0 17:30 18:00 11/15/2015 11/16/2015 6.00 COMPZN CASING PUTB P Run 4-1/2", 12.6 lb/ft,L-80, BTCM 0.0 5,041.0 18:00 00:00 slotted(79 jts)-4-1/2", 12.6 lb/ft, L-80, H563 blank(99 jts)with EZ Ream shoe,perforated pup jt with 36 x 0.5" holes,6 x 4-1/2"Frac sleeves with actuation ball sizes(1.75", 1.813", 1.875", 1.938",2.0",2.063"-btm to top order),followed by 4-1/2"sliding sleeve with 2.75""D"profile-open down. Make up BTCM liner with 7,500 ft-lb torque with Run and Seal thread dope and TQ-rings installed, MU 563 pipe to 5,600 ft-lb with Seal Guard dope applied. 11/16/2015 11/16/2015 1.75 COMPZN CASING PUTB P Continue to run 12.6 lb/ft,L-80, H563 5,061.0 6,796.0 00:00 01:45 blank(99 jts) 6 x 4-1/2"Frac sleeves with actuation ball sizes(1.75", 1.813", 1.875", 1.938",2.0",2.063"-btm to top order),followed by 4-1/2"sliding sleeve with 2.75""D"profile-open down. Make up H563 pipe to 5,600 ft- lb with Seal Guard dope applied. 11/16/2015 11/16/2015 1.25 COMPZN CASING OTHR P MU"DG"Flex-Lock liner 6,796.0 6,935.0 01:45 03:00 hanger/HRDE ZXP packer assembly and running tool. Mix&pour pal mix. MU XO to 1 stand 4"DP to 6,935'. SIMOPs-C/O elevators to 4"DP elevators. 11/16/2015 11/16/2015 0.50 COMPZN CASING CIRC P Break circ and circ liner volume with 1- 6,935.0 6,935.0 03:00 03:30 3 bpm,90-160 psi.Liner PU= 115K, S0= 100K. Blow down TD. 11/16/2015 11/16/2015 5.00 COMPZN CASING RUNL P RIH with 4-1/2"liner on 4"DP from 6,935.0 14,335.0 03:30 08:30 6,935'to 14,335' 11/16/2015 11/16/2015 0.50 COMPZN CASING CIRC P Break circ with 1-3 bpm, 170-340 psi. 14,335.0 14,335.0 08:30 09:00 PU= 185K,S0= 140K. Blow down TD. 11/16/2015 11/16/2015 4.75 COMPZN CASING RUNL P RIH with 4-1/2"liner on 4"DP from 14,335.0 20,999.0 09:00 13:45 14,335'to 20,999'(Tag bottom with 10 K Ib), PU 245K,SO 120K 11/16/2015 11/16/2015 0.75 COMPZN CASING CIRC P Circ&cond.Stage pumps from 2-4 20,999.0 20,990.0 13:45 14:30 bpm,430-960 psi. PJSM on displacement 11/16/2015 11/16/2015 3.25 COMPZN CASING DISP P Displace well to 9.5 ppg non- 20,990.0 20,990.0 14:30 17:45 viscosified brine: Pump 30 bbls high vis spacer,followed by 800 bbls 9.5 ppg brine at 4.5 bpm,960 psi while reciprocating pipe with 30'strokes. PU=240K,S0= 140K. Continue to reciprocate until pipe was abruptly stuck 1'below planned setting depth. Page 22/26 Report Printed: 12/17/2015 iterations Summary (with Timelogepths) &tll►Dri'+I CD5-03 Conoco 'hitlips R4:xk� Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE() 11/16/2015 11/16/2015 0.25 COMPZN CASING OWFF P Flow chk-static(slight drop in fluid 20,990.0 20,990.0 17:45 18:00 level,<1').. Break connection,blow down and drop 1.5"ball.Screw back in and PU to last up weight of 225K lb and put string in tension. 11/16/2015 11/16/2015 2.00 COMPZN CASING PACK P Pump ball down with 3-1.5 bpm,400 20,990.0 14,152.0 18:00 20:00 -100 psi, ball went on seat and pressured up to 2,580 psi. Held pressure for 2 min,slacked off from 225K to 125K lb,set hanger and release from running tool. Pressure up with 4,050 psi and hold for 5 minutes, bleed off to 0 psi. PU with 210K lb string weight(15K lb decrease)and continue to PU 6'verifying released from hanger and exposing dog sub. Slackoff to 150K lb without indication of shear but tagged higher. PU to 210K string weight,rotate down at 5 rpm while slacking off to 150K lb. Weight jumped indicating dogs sheared and packer set. Continue to slackoff to 125K lb. Repeat tag, confirm set and bleed off pressure. TOL at 14,152'and 11/16/2015 11/16/2015 0.75 COMPZN CASING PRTS P Blow down TD and RU head pin and 14,152.0 14,152.0 20:00 20:45 lines. Pressure test ZXP liner top packer to 2,000 psi for 10 min.,chart and record-good. RD testing equip. 11/16/2015 11/16/2015 0.25 COMPZN WELLPR OWFF P Flow chk-static(slight drop) 14,152.0 14,152.0 20:45 21:00 11/16/2015 11/16/2015 1.00 COMPZN WELLPR SLPC P PJSM.Slip&cut 75'drill line while 14,152.0 14,100.0 21:00 22:00 monitoring well. 11/16/2015 11/16/2015 0.75 COMPZN WELLPR SVRG P Adjust brakes,roller bands and 14,100.0 14,100.0 22:00 22:45 equalizer bar.Service TD, IR and drawworks.(3 bbl loss while monitoring well for 1.75 hr). 11/16/2015 11/17/2015 1.25 COMPZN WELLPR TRIP P POOH from 14,100 to 12,726'racking 14,100.0 12,726.0 22:45 00:00 back 4"DP and HWDP. 11/17/2015 11/17/2015 6.50 COMPZN WELLPR TRIP P POOH from 12,726'to 246'racking 12,726.0 246.0 00:00 06:30 back 4"DP and HWDP. 11/17/2015 11/17/2015 0.25 COMPZN WELLPR OWFF P Flo-chk-static.(dropped 1'in 246.0 246.0 06:30 06:45 annulus). 11/17/2015 11/17/2015 0.50 COMPZN WELLPR BHAH P POOH from 246',inspecting and 0.0 0.0 06:45 07:15 laying down liner running tool. Calc/Actual Fill for trip=99.2/113.5 bbl 11/17/2015 11/17/2015 0.75 COMPZN RPCOMP RURD P Pull wear ring and set 9"ID, 0.0 0.0 07:15 08:00 retrievable completion wear ring. SIMOPs:Clear and clean rig floor, bring completion tools and equipment to rig floor while monitoring well on the Trip tank. 11/17/2015 11/17/2015 1.50 COMPZN RPCOMP RURD P Continue to PU tools and equipment 0.0 0.0 08:00 09:30 to run completion(sheaves, I-Wire, cannon clamps,dbl stacked tongs). RU sheaves.Change out handling equipment. RU power tongs.(monitor well on Trip tank. Page 23/26 Report Printed: 12/17/2015 operations Summary (with Timeloggpths) Wells CD5-03 ConocoPhfthps Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE). 11/17/2015 11/17/2015 2.00 COMPZN RPCOMP PUTB P PJSM.Run 3-1/2"upper completion 0.0 536.0 09:30 11:30 as per detail to 536'.MU I Wire and test to 5,000 psi for 10 min(good). Cont.to run 3 1/2"upper completion as per detail f/370'to 8,375'(Test(- Wire every 1000') 11/17/2015 11/17/2015 0.50 COMPZN RPCOMP PUTB P Continue to run 3-1/2"upper 536.0 760.0 11:30 12:00 completion as per detail from 536'to 760'(Test I-Wire every 30 jts') 11/17/2015 11/18/2015 12.00 COMPZN RPCOMP PUTB P Continue to run 3-1/2"upper 760.0 6,726.0 12:00 00:00 completion as per detail from 760'to 6,726'(Test I-Wire every 30 jts') 11/18/2015 11/18/2015 13.25 COMPZN RPCOMP PUTB P Continue to run 3-1/2"upper 6,726.0 14,168.0 00:00 13:15 completion as per detail from 6,726'to 14,168'(Test I-Wire every 30 jts').Tag TOL and No-Go out setting down with 25K lb.Space out 4.02'from fully located. PU= 145K,SO=100K lb Note:3-1/2"tubing tail= 14,165'(WLEG depth) 11/18/2015 11/18/2015 1.25 COMPZN RPCOMP CRIH P Pump 25 bbls of Corrosion Inhibited 14,168.0 14,168.0 13:15 14:30 brine followed by 9.5 ppg brine and pump at 1-3 bpm,20-1,260 psi and spot CI brine from TOL to bottom of SOV. 11/18/2015 11/18/2015 0.25 COMPZN RPCOMP HOSO P POOH from 14,168'to 14,032'and LD 14,168.0 14,032.0 14:30 14:45 4 jts of excess 3 1/2"tubing used for space out via beaver slide. 11/18/2015 11/18/2015 0.75 COMPZN RPCOMP HOSO P MU 2 space out pup joints of 3-1/2", 14,032.0 14,131.0 14:45 15:30 EUE tbg(2.37'and 10.24').install 3- 1/2"x 4-1/2"XO, EUE x H563(PxB), MU 2 joints of 4-1/2", 12.6 lb/ft, L-80, H563 tbg(43.00'and 43.35')to 14,130.96' 11/18/2015 11/18/2015 0.50 COMPZN -RPCOMP RURD P MU ACME wear ring puller to landing 14,131.0 14,131.0 15:30 16:00 joint B. Pull wear ring. LD same 11/18/2015 11/18/2015 0.50 COMPZN RPCOMP THGR P MU tubing hanger and align. 14,131.0 14,131.0 16:00 16:30 11/18/2015 11/18/2015 1.00 COMPZN RPCOMP THGR P Terminate and feed I-wire through 14,131.0 14,131.0 16:30 17:30 hanger and test swedge lock connection to 5,000 psi for 5 min (good). 11/18/2015 11/18/2015 1.50 COMPZN RPCOMP THGR P MU landing joint A to tubing hanger 14,131.0 14,165.0 17:30 19:00 land 3-1/2"tubing on hanger.(No-Go 4.02'from fully located). Test hanger metal to metal seals to 250/5,000 psi, hi/low for 5/10 minutes and record. LD landing joint A. 11/18/2015 11/18/2015 1.00 COMPZN RPCOMP RURD P Drop Ball and Rod and let fall. LD I- 14,165.0 14,165.0 19:00 20:00 wire, completion tools. RU squeeze manifold and hoses. RIH landing jt B. Test squeeze manifold to 4000 psi (good) Page 24/26 Report Printed: 12/17/2015 iterations Summary (with Timelog!pths) We -y CD5-03 Chitiips ,aka Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2015 11/18/2015 2.00 COMPZN RPCOMP PRTS P Pressure test tubing to 3,500 psi for 14,165.0 14,165.0 20:00 22:00 30 min-good,(Premier production packer set @ 1,750 psi). Bleed down tbg pressure to 2,000 psi and hold. Pressure test IA to 3,500 psi for 30 min-good. Bleed down IA pressure to zero psi then tubing pressure to zero psi.Open tubing and pressure up IA shearing SOV at 3,500 psi. 11/18/2015 11/18/2015 1.00 COMPZN WHDBOP MPSP P Blow down lines,RD test equip. 14,165.0 0.0 22:00 23:00 Install TWC and test in the direction of flow to 2,500 psi for 15 minutes and record. 11/18/2015 11/19/2015 1.00 COMPZN WHDBOP WWWH P MU 4"DP to stack washer. Flush 0.0 0.0 23:00 00:00 stack with fresh H2O at 10 bpm,50 psi. LD I-wire equipment and power tongs. 11/19/2015 11/19/2015 1.25 COMPZN WHDBOP OTHR P Clear and clean rig floor.Continue to 0.0 0.0 00:00 01:15 LD I-wire equipment and power tongs. Blow down TD and lines. 11/19/2015 11/19/2015 1.25 COMPZN WHDBOP MPDA P PJSM. RD MPD RCD, flow lines, Trip 0.0 0.0 01:15 02:30 nipple and Orbit valve.SIMOPs-Strip off MPD element from 4"DP racked back in the derrick and LD. 11/19/2015 11/19/2015 1.25 COMPZN WHDBOP NUND P ND BOPE,break UPR and Blind ram 0.0 0.0 02:30 03:45 doors for BWM. SIMOPs-Change out Saver sub from 4"XT-39 to 5"DS50. 11/19/2015 11/19/2015 2.25 COMPZN WHDBOP NUND P Feed thru and terminate I-wire thru 0.0 0.0 03:45 06:00 well head.SIMOPs-Prep tree for NU, continue to c/o Saver-sub, clean and clear rig floor. PU FMC lubricator to rig floor. 11/19/2015 11/19/2015 0.75 COMPZN WHDBOP NUND P NU tree and fill with diesel. 0.0 0.0 06:00 06:45 11/19/2015 11/19/2015 2.75 COMPZN WHDBOP PRTS P Test void to 5,000 psi for 15 min.- 0.0 0.0 06:45 09:30 good. Test tree to 250/5000 psi for 10 min and record-(good). RD test equip. 11/19/2015 11/19/2015 0.25 COMPZN WHDBOP MPSP P Pull TWC 0.0 0.0 09:30 09:45 11/19/2015 11/19/2015 0.50 COMPZN WHDBOP FRZP P RU squeeze manifold and lines for 0.0 09:45 10:15 freeze protect. 11/19/2015 11/19/2015 2.50 COMPZN WHDBOP FRZP P PJSM.Test lines to 3,000 psi. Pump 0.0 0.0 10:15 12:45 92 bbls diesel freeze protect(w/cmt pump)down IA at 2.2 bpm, 40-1020 psi. Let u-tube across squeeze manifold at 290-300 psi.Final psi after u-tube 250 psi. 11/19/2015 11/19/2015 1.75 COMPZN WHDBOP MPSP P RU lubricator and test to 2,000 psi. 0.0 0.0 12:45 14:30 Install BPV and RD lubricator.Test BPV to 2,500 psi for 15 min in direction of flow. Bleed off psi to 350 psi and shut in well on IA. Flush lines with H2O and blow down. RD circ lines and equip.SIMOPs-install 90' mouse hole. Secure well. Page 25/26 Report Printed: 12/17/2015 Iterations Summary (with Timeloggepths) �1,;,1{ � CD5-03 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2015 11/20/2015 9.50 DEMOB MOVE PULD P L/D 135 stands of 4"DP from derrick 0.0 0.0 14:30 00:00 via mouse hole.Leave 26 stands of 4", 15.7 lb/ft DP and 20 stands of 5" DP in the derrick, for next well. 11/20/2015 11/20/2015 5.00 DEMOB MOVE PULD P LD 27 stands of 4"DP and 15 stands 0.0 0.0 00:00 05:00 of 4"HWDP from derrick via mouse hole. Leave 26 stands of 4", 15.7 lb/ft DP and 20 stands of 5"DP in the derrick, for next well. Install pipe skate roller. SIMOPs-Work on rig move check list and warm up Moving system for rig move. 11/20/2015 11/20/2015 1.00 DEMOB MOVE RURD P Pull and LD mouse hole for move. 0.0 0.0 05:00 06:00 Blow down water and steam to rig sub. Warm up Cold start generator. Take rig off of high-line power at 0600 hrs, 11/20/2015. Release rig from CD5-03 Daywork at 0600 hrs, 11/20/2015. Page 26/26 Report Printed: 12/17/2015 • • NADConversion Western North Slope CD5 Alpine West Pad CD5-03 Definitive Survey Report 30 November, 2015 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope ND Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Desi(n. CD5-03 Database: OAKEDMP2 Prct..' Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor ', i CD5-03 Well Position +N/-S 0.00 usft Northing: 5,965,904.95 usfl Latitude: 70° 18'50.253 N +E/-W 0.00 usft Easting: 349,500.86 usfl Longitude: 151°13'11.180 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 34.10 usft 'iliftilre CD5-03 1{ etics. Model Name Sample Date Declination Dip Angle Field Strength', ,..),.;,...,...../.,,,,,A.-4<,,� (°) (°) (nT) BGGM2015 11/6/2015 17.93 80.83 57,471 Deit,, CD5-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.83 Vertical Section: From(T +?4f +E]W Direction (u � ( (°) 0.00 0.00 0.00 331.00 Survey Program Date ' r-"1) ,�, From To � s `'' Wit:-, (usft) (usft) Survey(Wellbore) Tool Name Description % ,, Stirlte'Date 109.00 640.00 C0 5-03 Svyl -SLB_NSG+SSHOT(CD5 GYD-GC SS Gyrodata gyro single shots 10/20/2015 9:: 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:: 2,393.84 2,393.84 CD5-03 Svy3-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 2,446.61 3,012.81 CD5-03 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1: 3,107.13 3,107.13 CD5-03 SvyS-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 3,201.32 20,939.03 CD5-03 Svy6-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1:: Survey ,,,,,,,,,,,,,:,?,,,,--,'-1•, ' Map Map Vertical ifInc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) '•j(°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -34.10 0.00 0.00 5,965,904.95 349,500.86 0.00 0.00 UNDEFINED 109.00 0.41 157.11 109.00 38.07 -0.24 0.10 5,965,904.71 349,500.95 0.57 -0.26 GYD-GC-SS(1) 115.00 0.41 160.09 115.00 44.07 -0.28 0.12 5,965,904.67 349,500.97 0.36 -0.30 GYD-GC-SS(1) 20"x42" 181.00 0.49 188.69 181.00 110.07 -0.78 0.15 5,965,904.17 349,501.00 0.36 -0.76 GYD-GC-SS(1) 286.00 0.46 171.22 285.99 215.06 -1.64 0.15 5,965,903.31 349,500.97 0.14 -1.51 GYD-GC-SS(1) 379.00 0.40 315.40 378.99 308.06 -1.78 -0.02 5,965,903.18 349,500.80 0.88 -1.54 GYD-GC-SS(1) 456.00 1.32 332.42 455.98 385.05 -0.80 -0.62 5,965,904.16 349,500.22 1.23 -0.40 GYD-GC-SS(1) 547.00 3.64 342.74 546.89 475.96 2.89 -1.96 5,965,907.88 349,498.95 2.59 3.48 GYD-GC-SS(1) 640.00 5.10 341.44 639.62 568.69 9.63 -4.15 5,965,914.66 349,496.90 1.57 10.43 GYD-GC-SS(1) 11/30/2015 2:58:02PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: ``Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting OLS Section (usft) (0) (0) (usft) (usft) '(usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 706.73 6.66 341.30 706.00 635.07 16.10 -6.34 5,965,921.18 349,494.84 2.34 17.16 MWD+IFR-AK-CAZ-SC(2) 763.64 9.05 346.48 762.37 691.44 23.58 -8.44 5,965,928.70 349,492.89 4.38 24.72 MWD+IFR-AK-CAZ-SC(2) 857.86 10.91 350.45 855.16 784.23 39.58 -11.66 5,965,944.76 349,490.00 2.10 40.27 MWD+IFR-AK-CAZ-SC(2) 952.85 13.26 350.82 948.04 877.11 59.20 -14.89 5,965,964.44 349,487.16 2.48 59.00 MWD+IFR-AK-CAZ-SC(2) 1,046.87 16.13 351.66 1,038.97 968.04 82.78 -18.50 5,965,988.08 349,484.02 3.06 81.37 MWD+IFR-AK-CAZ-SC(2) 1,139.96 18.17 352.74 1,127.92 1,056.99 109.97 -22.21 5,966,015.34 349,480.86 2.22 106.95 MWD+IFR-AK-CAZ-SC(2) 1,234.44 19.22 353.12 1,217.41 1,146.48 140.02 -25.94 5,966,045.46 349,477.73 1.12 135.04 MWD+IFR-AK-CAZ-SC(2) 1,329.46 21.62 352.72 1,306.46 1,235.53 172.92 -30.03 5,966,078.43 349,474.30 2.53 165.80 MWD+IFR-AK-CAZ-SC(2) 1,423.98 22.55 352.28 1,394.04 1,323.11 208.15 -34.67 5,966,113.74 349,470.37 1.00 198.86 MWD+IFR-AK-CAZ-SC(2) 1,518.01 23.21 353.74 1,480.67 1,409.74 244.44 -39.11 5,966,150.11 349,466.65 0.93 232.75 MWD+IFR-AK-CAZ-SC(2) 1,612.52 26.26 355.12 1,566.50 1,495.57 283.79 -42.92 5,966,189.53 349,463.63 3.28 269.02 MWD+IFR-AK-CAZ-SC(2) 1,705.02 29.72 357.69 1,648.17 1,577.24 327.11 -45.59 5,966,232.88 349,461.84 3.96 308.19 MWD+IFR-AK-CAZ-SC(2) 1,799.69 33.51 1.37 1,728.79 1,657.86 376.70 -45.91 5,966,282.47 349,462.51 4.49 351.73 MWD+IFR-AK-CAZ-SC(2) 1,893.56 36.33 2.16 1,805.75 1,734.82 430.40 -44.24 5,966,336.12 349,465.25 3.04 397.89 MWD+IFR-AK-CAZ-SC(2) 1,987.71 39.54 2.93 1,879.99 1,809.06 488.22 -41.66 5,966,393.87 349,469.00 3.45 447.20 MWD+IFR-AK-CAZ-SC(2) 2,082.01 42.89 4.47 1,950.92 1,879.99 550.21 -37.62 5,966,455.76 349,474.27 3.71 499.46 MWD+IFR-AK-CAZ-SC(2) 2,175.54 46.13 7.05 2,017.62 1,946.69 615.42 -31.00 5,966,520.82 349,482.20 3.97 553.29 MWD+IFR-AK-CAZ-SC(2) 2,270.65 49.64 7.72 2,081.39 2,010.46 685.37 -21.92 5,966,590.58 349,492.68 3.73 610.07 MWD+IFR-AK-CAZ-SC(2) 2,332.23 52.58 9.87 2,120.05 2,049.12 732.73 -14.58 5,966,637.77 349,500.97 5.49 647.92 MWD+IFR-AK-CAZ-SC(2) 2,393.40 53.25 9.01 2,156.94 2,086.01 780.86 -6.58 5,966,685.73 349,509.93 1.57 686.15 INC+TREND(3) 10-314"x 13-112•• 2,393.84 53.25 9.00 2,157.20 2,086.27 781.21 6.52 5,966,686.08 349,509.99 1.57 686.42 INC+TREND(3) 2,446.61 54.40 8.42 2,188.35 2,117.42 823.32 -0.07 5,966,728.04 349,517.29 2.35 720.12 MWD+IFR-AK-CAZ-SC(4) 2,540.41 58.16 9.29 2,240.41 2,169.48 900.39 11.95 5,966,804.85 349,530.85 4.08 781.70 MWD+IFR-AK-CAZ-SC(4) 2,635.46 61.10 10.07 2,288.46 2,217.53 981.22 25.74 5,966,885.38 349,546.26 3.17 845.71 MWD+IFR-AK-CAZ-SC(4) 2,729.01 62.78 12.72 2,332.47 2,261.54 1,062.13 42.07 5,966,965.94 349,564.20 3.08 908.56 MWD+IFR-AK-CAZ-SC(4) 2,823.37 63.11 13.13 2,375.39 2,304.46 1,144.03 60.86 5,967,047.45 349,584.63 0.52 971.09 MWD+IFR-AK-CAZ-SC(4) 2,918.15 62.77 12.29 2,418.51 2,347.58 1,226.37 79.43 5,967,129.39 349,604.85 0.87 1,034.09 MWD+IFR-AK-CAZ-SC(4) 3,012.81 63.22 11.64 2,461.49 2,390.56 1,308.87 96.92 5,967,211.52 349,623.98 0.77 1,097.78 MWD+IFR-AK-CAZ-SC(4) 3,107.13 63.22 11.06 2,503.99 2,433.06 1,391.43 113.49 5,967,293.72 349,642.20 0.55 1,161.95 INC+TREND(5) 3,201.32 63.27 11.63 2,546.39 2,475.46 1,473.89 130.03 5,967,375.83 349,660.40 0.54 1,226.05 MWD+IFR-AK-CAZ-SC(6) 3,294.86 63.22 10.60 2,588.50 2,517.57 1,555.85 146.14 5,967,457.44 349,678.14 0.98 1,289.93 MWD+IFR-AK-CAZ-SC(6) 3,389.84 63.34 11.91 2,631.21 2,560.28 1,639.05 162.69 5,967,540.29 349,696.36 1.24 1,354.67 MWD+IFR-AK-CAZ-SC(6) 3,484.08 63.36 13.32 2,673.48 2,602.55 1,721.24 181.09 5,967,622.09 349,716.39 1.34 1,417.64 MWD+IFR-AK-CAZ-SC(6) 3,578.22 63.29 14.02 2,715.75 2,644.82 1,802.98 200.97 5,967,703.41 349,737.91 0.67 1,479.49 MWD+IFR-AK-CAZ-SC(6) 3,672.82 63.21 13.32 2,758.33 2,687.40 1,885.06 220.93 5,967,785.07 349,759.51 0.67 1,541.60 MWD+IFR-AK-CAZ-SC(6) 3,767.31 63.20 12.01 2,800.92 2,729.99 1,967.35 239.42 5,967,866.96 349,779.65 1.24 1,604.61 MWD+IFR-AK-CAZ-SC(6) 3,861.28 63.17 11.37 2,843.31 2,772.38 2,049.48 256.42 5,967,948.73 349,798.28 0.61 1,668.20 MWD+IFR-AK-CAZ-SC(6) 3,955.76 63.38 11.10 2,885.80 2,814.87 2,132.25 272.86 5,968,031.14 349,816.38 0.34 1,732.62 MWD+IFR-AK-CAZ-SC(6) 4,049.53 63.36 12.41 2,927.84 2,856.91 2,214.31 289.93 5,968,112.84 349,835.09 1.25 1,796.12 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Welts CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 "Database: OAKEDMP2 Survey „.. • al Map Map Vertical MD Inc Azi TVD TYDSS +N/-S - W Northing Easting DIS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) ('1100•), (ft) Survey Tool Name 4,143.15 63.31 13.77 2,969.85 2,898.92 2,295.80 308.88 5,968,193.93 349,855.67 1.30 1,858.20 MWD+IFR-AK-CAZ-SC(6) 4,236.34 62.87 14.41 3,012.03 2,941.10 2,376.39 329.11 5,968,274.10 349,877.51 0.77 1,918.88 MWD+IFR-AK-CAZ-SC(6) 4,330.40 63.05 13.48 3,054.79 2,983.86 2,457.70 349.30 5,968,354.98 349,899.32 0.90 1,980.21 MWD+IFR-AK-CAZ-SC(6) 4,425.49 62.81 11.86 3,098.07 3,027.14 2,540.31 367.87 5,968,437.19 349,919.54 1.54 2,043.46 MWD+IFR-AK-CAZ-SC(6) 4,519.13 62.92 10.68 3,140.77 3,069.84 2,622.03 384.16 5,968,518.56 349,937.46 1.13 2,107.04 MWD+IFR-AK-CAZ-SC(6) 4,613.19 63.14 10.08 3,183.43 3,112.50 2,704.49 399.26 5,968,600.70 349,954.21 0.61 2,171.84 MWD+IFR-AK-CAZ-SC(6) 4,706.78 63.07 9.44 3,225.77 3,154.84 2,786.75 413.41 5,968,682.65 349,970.01 0.61 2,236.92 MWD+IFR-AK-CAZ-SC(6) 4,801.41 63.04 10.64 3,268.65 3,197.72 2,869.81 428.12 5,968,765.40 349,986.37 1.13 2,302.44 MWD+IFR-AK-CAZ-SC(6) 4,895.24 63.11 12.17 3,311.14 3,240.21 2,951.82 444.66 5,968,847.04 350,004.56 1.46 2,366.14 MWD+IFR-AK-CAZ-SC(6) 4,990.46 62.94 13.50 3,354.34 3,283.41 3,034.55 463.51 5,968,929.38 350,025.06 1.26 2,429.37 MWD+IFR-AK-CAZ-SC(6) 5,084.21 63.08 12.56 3,396.88 3,325.95 3,115.94 482.34 5,969,010.37 350,045.52 0.91 2,491.42 MWD+IFR-AK-CAZ-SC(6) 5,177.74 62.91 14.45 3,439.36 3,368.43 3,196.96 501.80 5,969,090.98 350,066.60 1.81 2,552.85 MWD+IFR-AK-CAZ-SC(6) 5,271.95 63.01 14.28 3,482.18 3,411 25 3,278.25 522.62 5,969,171.83 350,089.04 0.19 2,613.85 MWD+IFR-AK-CAZ-SC(6) 5,365.66 63.01 12.62 3,524.72 3,453.79 3,359.46 542.04 5,969,252.63 350,110.08 1.58 2,675.46 MWD+IFR-AK-CAZ-SC(6) 5,459.19 62.97 10.81 3,567.19 3,496.26 3,441.05 558.96 5,969,333.85 350,128.63 1.72 2,738.62 MWD+IFR-AK-CAZ-SC(6) 5,553.61 63.32 11.12 3,609.85 3,538.92 3,523.75 574.98 5,969,416.21 350,146.31 0.47 2,803.18 MWD+IFR-AK-CAZ-SC(6) 5,647.87 62.93 9.93 3,652.46 3,581.53 3,606.41 590.34 5,969,498.54 350,163.32 1.20 2,868.03 MWD+IFR-AK-CAZ-SC(6) 5,741.96 63.21 8.40 3,695.07 3,624.14 3,689.22 603.70 5,969,581.06 350,178.33 1.48 2,933.99 MWD+IFR-AK-CAZ-SC(6) 5,836.40 63.11 10.71 3,737.72 3,666.79 3,772.31 617.69 5,969,663.85 350,193.98 2.19 2,999.88 MWD+IFR-AK-CAZ-SC(6) 5,930 92 63.05 12.55 3,780.51 3,709.58 3,854.86 634.68 5,969,746.03 350,212.62 1.74 3,063.84 MWD+IFR-AK-CAZ-SC(6) 6,025.42 63.21 12.06 3,823.23 3,752.30 3,937.22 652.64 5,969,828.00 350,232.23 0.49 3,127.16 MWD+IFR-AK-CAZ-SC(6) 6,118.98 63.17 12.69 3,865.42 3,794.49 4,018.78 670.54 5,969,909.19 350,251.75 0.60 3,189.82 MWD+IFR-AK-CAZ-SC(6) 6,212.97 63.14 14.23 3,907.87 3,836.94 4,100.33 690.05 5,969,990.33 350,272.90 1.46 3,251.69 MWD+IFR-AK-CAZ-SC(6) 6,307.33 63.07 13.39 3,950.56 3,879.63 4,182.05 710.14 5,970,071.62 350,294.62 0.80 3,313.42 MWD+IFR-AK-CAZ-SC(6) 6,401.88 63.05 12.47 3,993.39 3,922.46 4,264.20 729.00 5,970,153.37 350,315.12 0.87 3,376.13 MWD+IFR-AK-CAZ-SC(6) 6,495.08 63.07 11.69 4,035.62 3,964.69 4,345.45 746.39 5,970,234.25 350,334.14 0.75 3,438.76 MWD+IFR-AK-CAZ-SC(6) 6,589.70 63.31 10.63 4,078.30 4,007.37 4,428.30 762.73 5,970,316.75 350,352.14 1.03 3,503.30 MWD+IFR-AK-CAZ-SC(6) 6,683.25 63.10 10.57 4,120.47 4,049.54 4,510.38 778.10 5,970,398.50 350,369.14 0.23 3,567.64 MWD+IFR-AK-CAZ-SC(6) 6,778.11 63.28 10.89 4,163.25 4,092.32 4,593.56 793.86 5,970,481.34 350,386.56 0.36 3,632.75 MWD+IFR-AK-CAZ-SC(6) 6,872.00 63.08 12.00 4,205.62 4,134.69 4,675.68 810.48 5,970,563.11 350,404.83 1.08 3,696.52 MWD+IFR-AK-CAZ-SC(6) 6,966.53 63.28 11.56 4,248.27 4,177.34 4,758.27 827.71 5,970,645.32 350,423.70 0.47 3,760.40 MWD+IFR-AK-CAZ-SC(6) 7,061.06 63.17 10.95 4,290.85 4,219.92 4,841.04 844.18 5,970,727.74 350,441.83 0.59 3,824.80 MWD+IFR-AK-CAZ-SC(6) 7,152.64 63.11 10.27 4,332.23 4,261.30 4,921.34 859.22 5,970,807.72 350,458.48 0.67 3,887.74 MWD+IFR-AK-CAZ-SC(6) 7,245.91 63.11 11.41 4,374 41 4,303.48 5,003.04 874.86 5,970,889.08 350,475.75 1.09 3,951.62 MWD+IFR-AK-CAZ-SC(6) 7,340.45 63.04 10.97 4,417.23 4,346.30 5,085.73 891.22 5,970,971.42 350,493.76 0.42 4,016.01 MWD+IFR-AK-CAZ-SC(6) 7,434.38 63.15 11.56 4,459.73 4,388.80 5,167.88 907.59 5,971,053.22 350,511.77 0.57 4,079.92 MWD+IFR-AK-CAZ-SC(6) 7,528.64 63.02 12.13 4,502.40 4,431.47 5,250.14 924.84 5,971,135.11 350,530.67 0.56 4,143.50 MWD+IFR-AK-CAZ-SC(6) 7,623.79 63.05 13.32 4,545.55 4,474.62 5,332.86 943.52 5,971,217.43 350,551.00 1.12 4,206.80 MWD+IFR-AK-CAZ-SC(6) 7,718.35 63.11 14.15 4,588.36 4,517.43 5,414.76 963.54 5,971,298.91 350,572.65 0.79 4,268.72 MWD+IFR-AK-CAZ-SC(6) 7,812.20 63.06 14.00 4,630.84 4,559.91 5,495.93 983.89 5,971,379.65 350,594.63 0.15 4,329.85 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site:` CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design; CD5-03 Database: OAKEDMP2 Survey Map Map Vertical r; MD - Inc Azi T , NDS8 +N64 +El-W Northing, Easting 01-$ Section {u ft} -% • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 lJoct: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) ,8490 CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Wet1:-', CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 '1%4,2 "4 Map Vertical MD Inc Azi TVD VEISS +E/-W lit:ST:'`k,$ettion (usft) (0) (0) (usft) (tisk (us( usft) neoi, Survey Tool Nam) 11,666.71 63.12 13.25 6,375.85 6,304.92 8,854.27 1,711.78 5,974,722.48 351,389.63 0.05 6,914.23 MWD+IFR-AK-CAZ-SC(6) 11,760.40 63.04 12.17 6,418.27 6,347.34 8,935.76 1,730.16 5,974,803.58 351,409.64 1.03 6,976.59 MWD+IFR-AK-CAZ-SC(6) 11,854.28 63.09 11.07 6,460.80 6,389.87 9,017.74 1,747.02 5,974,885.19 351,428.13 1.05 7,040.12 MWD+IFR-AK-CAZ-SC(6) 11,949.26 62.98 11.98 6,503.87 6,432.94 9,100.68 1,763.93 5,974,967.78 351,446.70 0.86 7,104.47 MWD+IFR-AK-CAZ-SC(6) 12,041.95 63.26 12.06 6,545.77 6,474.84 9,181.55 1,781.15 5,975,048.27 351,465.54 0.31 7,166.84 MWD+IFR-AK-CAZ-SC(6) 12,135.18 63.25 12.35 6,587.73 6,516.80 9,262.92 1,798.75 5,975,129.27 351,484.76 0.28 7,229.48 MWD+IFR-AK-CAZ-SC(6) 12,228.87 62.94 13.17 6,630.13 6,559.20 9,344.40 1,817.20 5,975,210.36 351,504.84 0.85 7,291.80 MWD+IFR-AK-CAZ-SC(6) 12,322.52 63.31 12.62 6,672.46 6,601.53 9,425.83 1,835.84 5,975,291.40 351,525.11 0.66 7,353.99 MWD+IFR-AK-CAZ-SC(6) 12,417.38 63.05 11.60 6,715.26 6,644.33 9,508.60 1,853.60 5,975,373.79 351,544.53 1.00 7,417.77 MWD+IFR-AK-CAZ-SC(6) 12,510.87 63.02 11.00 6,757.65 6,686.72 9,590.31 1,869.93 5,975,455.15 351,562.49 0.57 7,481.32 MWD+IFR-AK-CAZ-SC(6) 12,603.06 63.12 11.24 6,799.41 6,728.48 9,670.96 1,885.78 5,975,535.46 351,579.95 0.26 7,544.17 MWD+IFR-AK-CAZ-SC(6) 12,697.18 62.84 10.81 6,842.17 6,771.24 9,753.26 1,901.82 5,975,617.41 351,597.63 0.50 7,608.38 MWD+IFR-AK-CAZ-SC(6) 12,790.91 63.09 10.44 6,884.77 6,813.84 9,835.32 1,917.21 5,975,699.14 351,614.66 0.44 7,672.68 MWD+IFR-AK-CAZ-SC(6) 12,884.80 63.17 10.47 6,927.20 6,856.27 9,917.68 1,932.41 5,975,781.17 351,631.51 0.09 7,737.35 MWD+IFR-AK-CAZ-SC(6) 12,978.94 63.08 10.31 6,969.76 6,898.83 10,000.28 1,947.55 5,975,863.44 351,648.30 0.18 7,802.25 MWD+IFR-AK-CAZ-SC(6) 13,072.28 63.13 10.29 7,011.98 6,941.05 10,082.18 1,962.44 5,975,945.02 351,664.83 0.06 7,866.66 MWD+IFR-AK-CAZ-SC(6) 13,166.26 63.71 9.53 7,054.03 6,983.10 10,164.97 1,976.90 5,976,027.50 351,680.94 0.95 7,932.06 MWD+IFR-AK-CAZ-SC(6) 13,259.54 65.07 6.32 7,094.36 7,023.43 10,248.27 1,988.48 5,976,110.55 351,694.19 3.43 7,999.30 MWD+IFR-AK-CAZ-SC(6) 13,353.66 65.36 3.42 7,133.82 7,062.89 10,333.40 1,995.73 5,976,195.51 351,703.15 2.81 8,070.24 MWD+IFR-AK-CAZ-SC(6) 13,447.09 65.82 1.29 7,172.44 7,101.51 10,418.40 1,999.22 5,976,280.41 351,708.34 2.13 8,142.89 MWD+IFR-AK-CAZ-SC(6) 13,540.30 67.13 359.30 7,209.65 7,138.72 10,503.85 1,999.66 5,976,365.84 351,710.49 2.41 8,217.42 MWD+IFR-AK-CAZ-SC(6) 13,634.11 69.29 356.39 7,244.47 7,173.54 10,590.88 1,996.37 5,976,452.91 351,708.94 3.69 8,295.14 MWD+IFR-AK-CAZ-SC(6) 13,727.73 71.67 354.23 7,275.76 7,204.83 10,678.81 1,989.14 5,976,540.96 351,703.48 3.35 8,375.54 MWD+IFR-AK-CAZ-SC(6) 13,821.63 73.64 352.97 7,303.75 7,232.82 10,767.87 1,979.14 5,976,630.20 351,695.27 2.46 8,458.29 MWD+IFR-AK-CAZ-SC(6) 13,915.09 74.45 351.64 7,329.44 7,258.51 10,856.92 1,967.11 5,976,719.46 351,685.03 1.62 8,542.00 MWD+IFR-AK-CAZ-SC(6) 14,008.99 77.21 349.76 7,352.43 7,281.50 10,946.75 1,952.39 5,976,809.56 351,672.11 3.52 8,627.71 MWD+IFR-AK-CAZ-SC(6) 14,102.96 79.55 346.72 7,371 36 7,300.43 11,036.85 1,933.62 5,976,900.01 351,655.16 4.03 8,715.60 MWD+IFR-AK-CAZ-SC(6) 14,196.39 82.58 343.00 7,385.87 7,314.94 11,125.91 1,909.51 5,976,989.53 351,632.84 5.10 8,805.19 MWD+IFR-AK-CAZ-SC(6) 14,290.68 85.43 340.62 7,395.72 7,324.79 11,214.98 1,880.24 5,977,079.16 351,605.36 3.93 8,897.28 MWD+IFR-AK-CAZ-SC(6) 14,340.65 86.94 338.69 7,399.04 7,328.11 11,261.72 1,862.90 5,977,126.24 351,588.96 4.91 8,946.57 MWD+IFR-AK-CAZ-SC(6) 7-5/8"x 9-718"by 11" 14,385 36 88.30 336.96 7,400.90 7,329.97 11,303.09 1,846.04 5,977,167.93 351,572.94 4.91 8,990.92 MWD+IFR-AK-CAZ-SC(6) 14,418.67 89.04 335.19 7,401.67 7,330.74 11,333.53 1,832.54 5,977,198.63 351,560.05 5.76 9,024.09 MWD+IFR-AK-CAZ-SC(6) 14,514.76 91.30 330.78 7,401.39 7,330.46 11,419.10 1,788.91 5,977,285.06 351,518.14 5.16 9,120.09 MWD+IFR-AK-CAZ-SC(6) 14,608.02 90.79 329.62 7,399.69 7,328.76 11,500.02 1,742.57 5,977,366.88 351,473.44 1.36 9,213.33 MWD+IFR-AK-CAZ-SC(6) 14,704.29 91.55 327.85 7,397.72 7,326.79 11,582.29 1,692.62 5,977,450.13 351,425.15 2.00 9,309.50 MWD+IFR-AK-CAZ-SC(6) 14,798.61 91.64 326.93 7,395.10 7,324.17 11,661.71 1,641.81 5,977,530.54 351,375.94 0.98 9,403.59 MWD+IFR-AK-CAZ-SC(6) 14,893.77 91.57 326.08 7,392.43 7,321.50 11,741.03 1,589.31 5,977,610.90 351,325.05 0.90 9,498.42 MWD+IFR-AK-CAZ-SC(6) 14,988.78 91.63 326.49 7,389.78 7,318.85 11,820.03 1,536.60 5,977,690.93 351,273.93 0.44 9,593.07 MWD+IFR-AK-CAZ-SC(6) 15,084.07 90.06 325.97 7,388.37 7,317.44 11,899.23 1,483.64 5,977,771.17 351,222.58 1.74 9,688.02 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map %' 'Map- Vertical MD Inc Azi TVD TVDSS +Nf-S +E/-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft)` (ft) (°1100')' (ft) Survey Tool Name 15,180.90 90.24 325.84 7,388.12 7,317.19 11,979.42 1,429.36 5,977,852.42 351,169.92 0.23 9,784.47 MWD+IFR-AK-CAZ-SC(6) 15,275.81 90.42 326.79 7,387.57 7,316.64 12,058.39 1,376.72 5,977,932.43 351,118.88 1.02 9,879.06 MWD+IFR-AK-CAZ-SC(6) 15,370.39 89.62 327.37 7,387.54 7,316.61 12,137.78 1,325.32 5,978,012.83 351,069.08 1.04 9,973.42 MWD+IFR-AK-CAZ-SC(6) 15,465.39 89.31 330.83 7,388.43 7,317.50 12,219.28 1,276.54 5,978,095.29 351,021.95 3.66 10,068.34 MWD+IFR-AK-CAZ-SC(6) 15,561.80 89.35 334.66 7,389.55 7,318.62 12,304.97 1,232.40 5,978,181.83 350,979.54 3.97 10,164.69 MWD+IFR-AK-CAZ-SC(6) 15,656.70 89.69 336.14 7,390.35 7,319.42 12,391.25 1,192.90 5,978,268.88 350,941.78 1.60 10,259.30 MWD+IFR-AK-CAZ-SC(6) 15,752.09 89.65 335.78 7,390.90 7,319.97 12,478.36 1,154.04 5,978,356.75 350,904.68 0.38 10,354.33 MWD+IFR-AK-CAZ-SC(6) 15,848.54 89.76 334.42 7,391.40 7,320.47 12,565.84 1,113.43 5,978,445.02 350,865.83 1.41 10,450.53 MWD+IFR-AK-CAZ-SC(6) 15,944.42 89.77 334.75 7,391.79 7,320.86 12,652.44 1,072.28 5,978,532.42 350,826.43 0.34 10,546.22 MWD+IFR-AK-CAZ-SC(6) 16,039.41 88.83 335.18 7,392.95 7,322.02 12,738.50 1,032.09 5,978,619.26 350,787.98 1.09 10,640.98 MWD+IFR-AK-CAZ-SC(6) 16,135.23 88.80 335.25 7,394.93 7,324.00 12,825.48 991.93 5,978,707.02 350,749.57 0.08 10,736.52 MWD+IFR-AK-CAZ-SC(6) 16,230.34 89.84 333.71 7,396.06 7,325.13 12,911.30 950.96 5,978,793.64 350,710.33 1.95 10,831.44 MWD+IFR-AK-CAZ-SC(6) 16,325.78 89.93 333.41 7,396.25 7,325.32 12,996.75 908.46 5,978,879.92 350,669.56 0.33 10,926.78 MWD+IFR-AK-CAZ-SC(6) 16,419.08 90.79 332.71 7,395.66 7,324.73 13,079.92 866.19 5,978,963.92 350,628.97 1.19 11,020.02 MWD+IFR-AK-CAZ-SC(6) 16,514.32 91.23 332.81 7,393.99 7,323.06 13,164.59 822.61 5,979,049.43 350,587.09 0.47 11,115.20 MWD+IFR-AK-CAZ-SC(6) 16,609.87 91.20 332.59 7,391.96 7,321.03 13,249.48 778.79 5,979,135.18 350,544.99 0.23 11,210.69 MWD+IFR-AK-CAZ-SC(6) 16,705.02 91.23 331.55 7,389.94 7,319.01 13,333.52 734.24 5,979,220.09 350,502.13 1.09 11,305.80 MWD+IFR-AK-CAZ-SC(6) 16,801.11 91.34 331.58 7,387.79 7,316.86 13,418.00 688.49 5,979,305.46 350,458.09 0.12 11,401.86 MWD+IFR-AK-CAZ-SC(6) 16,896.86 90.85 330.99 7,385.96 7,315.03 13,501.96 642.50 5,979,390.32 350,413.79 0.80 11,497.59 MWD+IFR-AK-CAZ-SC(6) 16,991.58 90.00 331.09 7,385.25 7,314.32 13,584.83 596.64 5,979,474.09 350,369.61 0.90 11,592.31 MWD+IFR-AK-CAZ-SC(6) 17,087.48 89.89 330.24 7,385.35 7,314.42 13,668.43 549.66 5,979,558.61 350,324.31 0.89 11,688.20 MWD+IFR-AK-CAZ-SC(6) 17,184.52 90.17 330.30 7,385.30 7,314.37 13,752.70 501.53 5,979,643.82 350,277.89 0.30 11,785.24 MWD+IFR-AK-CAZ-SC(6) 17,278.91 90.80 331.06 7,384.50 7,313.57 13,835.00 455.31 5,979,727.02 350,233.33 1.05 11,879.62 MWD+IFR-AK-CAZ-SC(6) 17,373.47 90.85 331.69 7,383.14 7,312.21 13,917.99 410.02 5,979,810.89 350,189.71 0.67 11,974.17 MWD+IFR-AK-CAZ-SC(6) 17,469.08 90.34 331.37 7,382.14 7,311.21 14,002.03 364.44 5,979,895.83 350,145.84 0.63 12,069.77 MWD+IFR-AK-CAZ-SC(6) 17,563.66 90.41 332.64 7,381.52 7,310.59 14,085.54 320.05 5,979,980.20 350,103.13 1.34 12,164.33 MWD+IFR-AK-CAZ-SC(6) 17,659.45 90.44 333.60 7,380.81 7,309.88 14,170.98 276.74 5,980,066.48 350,061.55 1.00 12,260.05 MWD+IFR-AK-CAZ-SC(6) 17,753.82 90.34 334.97 7,380.17 7,309.24 14,256.00 235.80 5,980,152.30 350,022.32 1.46 12,354.26 MWD+IFR-AK-CAZ-SC(6) 17,849.43 90.37 335.22 7,379.58 7,308.65 14,342.72 195.53 5,980,239.80 349,983.80 0.26 12,449.62 MWD+IFR-AK-CAZ-SC(6) 17,944.77 90.34 335.47 7,378.99 7,308.06 14,429.36 155.76 5,980,327.22 349,945.78 0.26 12,544.69 MWD+IFR-AK-CAZ-SC(6) 18,040.83 90.27 335.89 7,378.48 7,307.55 14,516.90 116.20 5,980,415.52 349,907.99 0.44 12,640.43 MWD+IFR-AK-CAZ-SC(6) 18,134.93 90.00 336.02 7,378.25 7,307.32 14,602.83 77.86 5,980,502.20 349,871.38 0.32 12,734.17 MWD+IFR-AK-CAZ-SC(6) 18,230.43 89.41 335.35 7,378.75 7,307.82 14,689.86 38.54 5,980,589.99 349,833.81 0.93 12,829.35 MWD+IFR-AK-CAZ-SC(6) 18,325.63 88.87 334.66 7,380.18 7,309.25 14,776.13 -1.68 5,980,677.05 349,795.33 0.92 12,924.31 MWD+IFR-AK-CAZ-SC(6) 18,421.05 88.42 334.65 7,382.43 7,311.50 14,862.34 -42.51 5,980,764.06 349,756.23 0.47 13,019.51 MWD+IFR-AK-CAZ-SC(6) 18,515.56 87.84 333.91 7,385.52 7,314.59 14,947.44 -83.51 5,980,849.95 349,716.96 0.99 13,113.81 MWD+IFR-AK-CAZ-SC(6) 18,612.05 87.32 333.45 7,389.59 7,318.66 15,033.85 -126.25 5,980,937.20 349,675.96 0.72 13,210.11 MWD+IFR-AK-CAZ-SC(6) 18,708.10 86.70 333.00 7,394.60 7,323.67 15,119.49 -169.46 5,981,023.67 349,634.48 0.80 13,305.96 MWD+IFR-AK-CAZ-SC(6) 18,802.30 88.73 333.65 7,398.36 7,327.43 15,203.59 -211.71 5,981,108.60 349,593.92 2.26 13,400.00 MWD+IFR-AK-CAZ-SC(6) 18,891.28 92.08 332.15 7,397.73 7,326.80 15,282.78 -252.24 5,981,188.59 349,554.99 4.12 13,488.91 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,988.75 94.04 331.45 7,392.52 7,321.59 15,368.56 -298.23 5,981,275.26 349,510.73 2.13 13,586.23 MWD+IFR-AK-CAZ-SC(6) 19,087.81 94.15 330.07 7,385.45 7,314.52 15,454.77 -346.49 5,981,362.42 349,464.21 1.39 13,685.03 MWD+IFR-AK-CAZ-SC(6) 19,183.81 94.22 328.41 7,378.44 7,307.51 15,537.04 -395.46 5,981,445.65 349,416.91 1.73 13,780.73 MWD+IFR-AK-CAZ-SC(6) 19,278.08 94.18 328.83 7,371.54 7,300.61 15,617.31 -444.41 5,981,526.87 349,369.58 0.45 13,874.66 MWD+IFR-AK-CAZ-SC(6) 19,372.36 94.15 328.37 7,364.69 7,293.76 15,697.57 -493.41 5,981,608.09 349,322.21 0.49 13,968.61 MWD+IFR-AK-CAZ-SC(6) 19,468.80 93.99 328.43 7,357.85 7,286.92 15,779.50 -543.81 5,981,691.01 349,273.46 0.18 14,064.71 MWD+IFR-AK-CAZ-SC(6) 19,563.70 93.15 327.57 7,351.94 7,281.01 15,859.82 -594.00 5,981,772.32 349,224.89 1.27 14,159.29 MWD+IFR-AK-CAZ-SC(6) 19,659.57 93.21 329.81 7,346.62 7,275.69 15,941.60 -643.74 5,981,855.07 349,176.80 2.33 14,254.93 MWD+IFR-AK-CAZ-SC(6) 19,753.65 92.02 329.85 7,342.33 7,271.40 16,022.85 -690.97 5,981,937.24 349,131.21 1.27 14,348.89 MWD+IFR-AK-CAZ-SC(6) 19,849.98 91.13 331.05 7,339.68 7,268.75 16,106.62 -738.46 5,982,021.94 349,085.42 1.55 14,445.18 MWD+IFR-AK-CAZ-SC(6) 19,945.55 90.13 329.96 7,338.63 7,267.70 16,189.79 -785.51 5,982,106.04 349,040.05 1.55 14,540.74 MWD+IFR-AK-CAZ-SC(6) 20,040.96 90.06 330.35 7,338.47 7,267.54 16,272.55 -832.99 5,982,189.72 348,994.24 0.42 14,636.14 MWD+IFR-AK-CAZ-SC(6) 20,135.12 90.13 331.41 7,338.31 7,267.38 16,354.81 -878.82 5,982,272.87 348,950.08 1.13 14,730.29 MWD+IFR-AK-CAZ-SC(6) 20,231.42 90.10 330.96 7,338.12 7,267.19 16,439.18 -925.23 5,982,358.16 348,905.37 0.47 14,826.59 MWD+IFR-AK-CAZ-SC(6) 20,326.61 90.13 332.00 7,337.93 7,267.00 16,522.82 -970.68 5,982,442.68 348,861.60 1.09 14,921.78 MWD+IFR-AK-CAZ-SC(6) 20,421.08 90.03 332.62 7,337.80 7,266.87 16,606.47 -1,014.58 5,982,527.19 348,819.39 0.66 15,016.22 MWD+IFR-AK-CAZ-SC(6) 20,516.76 90.59 333.38 7,337.28 7,266.35 16,691.72 -1,058.02 5,982,613.28 348,777.68 0.99 15,111.84 MWD+IFR-AK-CAZ-SC(6) 20,613.10 90.65 333.89 7,336.24 7,265.31 16,778.03 -1,100.80 5,982,700.43 348,736.64 0.53 15,208.07 MWD+IFR-AK-CAZ-SC(6) 20,707.11 90.58 332.93 7,335.23 7,264.30 16,862.09 -1,142.87 5,982,785.31 348,696.26 1.02 15,302.00 MWD+IFR-AK-CAZ-SC(6) 20,802.44 90.58 333.31 7,334.26 7,263.33 16,947.12 -1,185.97 5,982,871.18 348,654.88 0.40 15,397.25 MWD+IFR-AK-CAZ-SC(6) 20,898.28 90.65 334.48 7,333.23 7,262.30 17,033.18 -1,228.14 5,982,958.06 348,614.45 1.22 15,492.97 MWD+IFR-AK-CAZ-SC(6) 20,939.03 90.72 333.72 7,332.75 7,261.82 17,069.83 -1,245.94 5,982,995.06 348,597.39 1.87 15,533.65 MWD+IFR-AK-CAZ-SC(6) 20,990.00 90.72 333.72 7,332.11 7,261.18 17,115.53 -1,268.50 5,983,041.20 348,575.74 0.00 15,584.56 4-1/2"x 6-112" 20,999.00 90.72 333.72 7,331.99 7,261.06 17,123.60 -1,272.49 5,983,049.34 348,571.92 0.00 15,593.55 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. J Yes l have checked to the best of my ability that the following data is correct: j j Surface Coordinates Ej Declination & Convergence u GRS Survey Corrections Survey Tool Codes Vincent Digirae'isigned brVincent 0.ra ON.cn VlrrteM osafa: O::SChlUmberger,OU.SlYliivr,bergeC SLB DL �s a r a Dale 2015.11 24 Cls.11.i41433..4C4-US, aa w ` Client Representative_ Welfeng Dal 24-Nov-2015 Date: 11/30/2015 2:58:02PM Page 8 COMPASS 5000.1 Build 74 • Cement Detail Report 0 Drilling CD5-03 ConocoPhitlips i4isks String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/18/2015 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/21/2015 13:15 10/21/2015 16:03 CD5-03 Comment PJSM. Surface cement job: Dowell pump 1.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 75 bbls 11 ppg Mud Push II, Drop bottom plug, Dowell pump 26 bbls of 11.0 ppg Scavenger,360 bbls total 11.0 ppg Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 5.7 bpm,225-460 psi. Dowell pump 57 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 3.3 bpm/390-180 psi. Drop top plug. Dowell pump 10 bbls H20. Rig displace with 211.3 bbls of 10.0 ppg DrillPlex spud mud with YP=19. Initial 8 bpm at 580 psi,decreasing to 3 bpm at 500 psi. Increase to 500 psi over at 1,000 psi and hold for 5 min.Check floats- good. Full returns throughout 250 bbls good cement back to surface. Reciprocated pipe with 12'stroke until MudPush exited shoe.Stopped reciprocating due to excess drag and hole appearing to getting sticky.CIP at 16:03 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Returns to Surface 35.9 2,393.4 Yes 250.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 500.0 1,000.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,297.0 Drill Bit 2,393.4 9 7/8 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 35.9 1,893.0 1,058 G 360.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 5.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,893.0 2,393.0 274 G 57.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/9/2015 DrillingCement Detail Report _, &Wells CD5-03 ConocoPhillips AA.ka String: Intermediate 2 Stage Cement Job: DRILLING SUPPORT-CAPITAL, 10/27/20... Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 2 Stage Cement 11/1/2015 16:15 11/2/2015 00:15 CD5-03 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate 1st Stage Cement 7 5/8"Shoe 13,340.0 14,340.7 No Yes Yes Cement Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 320.0 850.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment No Returns Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 13,340.0 14,340.7 424 G 87.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 4.75 500.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate 2nd Stage Iscolate Qaanik formation 6,877.0 6,977.0 No No Yes Cement Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 200.0 2,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment No Returns Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 6,877.0 6,977.0 441 G 91.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/9/2015 • • 215146 2 497 Schiumberger E ! D Transmittal#: 04D15-S 0 Drilling & Measurements DATA LOGGED IJLL 0 4 Zu15 MWD/LWD Log Product Delivery t2iq/201S M.K.BENDER AOGCC Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-03**RE, Date Dispatched: 4-Dec-15 Job#: 15AKA0027 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: Contents on CD N/A Scope Resistivity 2"TVD Scope Resistivity 5" MD Scope Resistivity 5"TVD LAS Digital Data N/A Contents on CD Directional Data 1 Contents on CD Nad27 x x **REVISED ownhole As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x __ Graphics:pdf/tiff x Survey:pdf/txt**Revised** x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico@conocophillips.com AlaskaPTSPrintCenterslb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: ix) ✓w ,_ 11 • • 21 51 46 26497 REVISED 3:22 pm, Dec 03, 2015 NADConversion Western North Slope E7:i CD5 Alpine West Pad L 04 CD5-03 AOGCC Definitive Survey Report 30 November, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska, United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-03 Well Position +N/-S 0.00 usft Northing: 5,965,904.95 usfl Latitude: 70° 18'50.253 N +E/-W 0.00 usft Easting: 349,500.86 usfl Longitude: 151° 13'11.180 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 34.10 usft Wellbore CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2015 11/6/2015 17.93 80.83 57,471 Design CD5-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.83 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 331.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 109.00 640.00 CD5-03 Svy1 -SLB_NSG+SSHOT(CD5 GYD-GC-SS Gyrodata gyro single shots 10/20/2015 9:: 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:: 2,393.84 2,393.84 CD5-03 Svy3-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 2,446.61 3,012.81 CD5-03 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1: 3,107.13 3,107.13 CD5-03 Svy5-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 3,201.32 20,939.03 CD5-03 Svy6-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -34.10 0.00 0.00 5,965,904.95 349,500.86 0.00 0.00 UNDEFINED 109.00 0.41 157.11 109.00 38.07 -0.24 0.10 5,965,904.71 349,500.95 0.57 -0.26 GYD-GC-SS(1) 115.00 0.41 160.09 115.00 44.07 -0.28 0.12 5,965,904.67 349,500.97 0.36 -0.30 NOT an Actual Survey 20"x42" 181.00 0.49 188.69 181.00 110.07 -0.78 0.15 5,965,904.17 349,501.00 0.36 -0.76 GYD-GC-SS(1) 286.00 0.46 171.22 285.99 215.06 -1.64 0.15 5,965,903.31 349,500.97 0.14 -1.51 GYD-GC-SS(1) 379.00 0.40 315.40 378.99 308.06 -1.78 -0.02 5,965,903.18 349,500.80 0.88 -1.54 GYD-GC-SS(1) 456.00 1.32 332.42 455.98 385.05 -0.80 -0.62 5,965,904.16 349,500.22 1.23 -0.40 GYD-GC-SS(1) 547.00 3.64 342.74 546.89 475.96 2.89 -1.96 5,965,907.88 349,498.95 2.59 3.48 GYD-GC-SS(1) 640.00 5.10 341.44 639.62 568.69 9.63 -4.15 5,965,914.66 349,496.90 1.57 10.43 GYD-GC-SS(1) 11/30/2015 2:58:02PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 706.73 6.66 341.30 706.00 635.07 16.10 -6.34 5,965,921.18 349,494.84 2.34 17.16 MWD+IFR-AK-CAZ-SC(2) 763.64 9.05 346.48 762.37 691.44 23.58 -8.44 5,965,928.70 349,492.89 4.38 24.72 MWD+IFR-AK-CAZ-SC(2) 857.86 10.91 350.45 855.16 784.23 39.58 -11.66 5,965,944.76 349,490.00 2.10 40.27 MWD+IFR-AK-CAZ-SC(2) 952.85 13.26 350.82 948.04 877.11 59.20 -14.89 5,965,964.44 349,487.16 2.48 59.00 MWD+IFR-AK-CAZ-SC(2) 1,046.87 16.13 351.66 1,038.97 968.04 82.78 -18.50 5,965,988.08 349,484.02 3.06 81.37 MWD+IFR-AK-CAZ-SC(2) 1,139.96 18.17 352.74 1,127.92 1,056.99 109.97 -22.21 5,966,015.34 349,480.86 2.22 106.95 MWD+IFR-AK-CAZ-SC(2) 1,234.44 19.22 353.12 1,217.41 1,146.48 140.02 -25.94 5,966,045.46 349,477.73 1.12 135.04 MWD+IFR-AK-CAZ-SC(2) 1,329.46 21.62 352.72 1,306.46 1,235.53 172.92 -30.03 5,966,078.43 349,474.30 2.53 165.80 MWD+IFR-AK-CAZ-SC(2) 1,423.98 22.55 352.28 1,394.04 1,323.11 208.15 -34.67 5,966,113.74 349,470.37 1.00 198.86 MWD+IFR-AK-CAZ-SC(2) 1,518.01 23.21 353.74 1,480.67 1,409.74 244.44 -39.11 5,966,150.11 349,466.65 0.93 232.75 MWD+IFR-AK-CAZ-SC(2) 1,612.52 26.26 355.12 1,566.50 1,495.57 283.79 -42.92 5,966,189.53 349,463.63 3.28 269.02 MWD+IFR-AK-CAZ-SC(2) 1,705.02 29.72 357.69 1,648.17 1,577.24 327.11 -45.59 5,966,232.88 349,461.84 3.96 308.19 MWD+IFR-AK-CAZ-SC(2) 1,799.69 33.51 1.37 1,728.79 1,657.86 376.70 -45.91 5,966,282.47 349,462.51 4.49 351.73 MWD+IFR-AK-CAZ-SC(2) 1,893.56 36.33 2.16 1,805.75 1,734.82 430.40 -44.24 5,966,336.12 349,465.25 3.04 397.89 MWD+IFR-AK-CAZ-SC(2) 1,987.71 39.54 2.93 1,879.99 1,809.06 488.22 -41.66 5,966,393.87 349,469.00 3.45 447.20 MWD+IFR-AK-CAZ-SC(2) 2,082.01 42.89 4.47 1,950.92 1,879.99 550.21 -37.62 5,966,455.76 349,474.27 3.71 499.46 MWD+IFR-AK-CAZ-SC(2) 2,175.54 46.13 7.05 2,017.62 1,946.69 615.42 -31.00 5,966,520.82 349,482.20 3.97 553.29 MWD+IFR-AK-CAZ-SC(2) 2,270.65 49.64 7.72 2,081.39 2,010.46 685.37 -21.92 5,966,590.58 349,492.68 3.73 610.07 MWD+IFR-AK-CAZ-SC(2) 2,332.23 52.58 9.87 2,120.05 2,049.12 732.73 -14.58 5,966,637.77 349,500.97 5.49 647.92 MWD+IFR-AK-CAZ-SC(2) 2,393.40 53.25 9.01 2,156.94 2,086.01 780.86 -6.58 5,966,685.73 349,509.93 1.57 686.15 NOT an Actual Survey 10-3/4"x 13-1/2" 2,393.84 53.25 9.00 2,157.20 2,086.27 781.21 -6.52 5,966,686.08 349,509.99 1.57 686.42 INC+TREND(3) 2,446.61 54.40 8.42 2,188.35 2,117.42 823.32 -0.07 5,966,728.04 349,517.29 2.35 720.12 MWD+IFR-AK-CAZ-SC(4) 2,540.41 58.16 9.29 2,240.41 2,169.48 900.39 11.95 5,966,804.85 349,530.85 4.08 781.70 MWD+IFR-AK-CAZ-SC(4) 2,635.46 61.10 10.07 2,288.46 2,217.53 981.22 25.74 5,966,885.38 349,546.26 3.17 845.71 MWD+IFR-AK-CAZ-SC(4) 2,729.01 62.78 12.72 2,332.47 2,261.54 1,062.13 42.07 5,966,965.94 349,564.20 3.08 908.56 MWD+IFR-AK-CAZ-SC(4) 2,823.37 63.11 13.13 2,375.39 2,304.46 1,144.03 60.86 5,967,047.45 349,584.63 0.52 971.09 MWD+IFR-AK-CAZ-SC(4) 2,918.15 62.77 12.29 2,418.51 2,347.58 1,226.37 79.43 5,967,129.39 349,604.85 0.87 1,034.09 MWD+IFR-AK-CAZ-SC(4) 3,012.81 63.22 11.64 2,461.49 2,390.56 1,308.87 96.92 5,967,211.52 349,623.98 0.77 1,097.78 MWD+IFR-AK-CAZ-SC(4) 3,107.13 63.22 11.06 2,503.99 2,433.06 1,391.43 113.49 5,967,293.72 349,642.20 0.55 1,161.95 INC+TREND(5) 3,201.32 63.27 11.63 2,546.39 2,475.46 1,473.89 130.03 5,967,375.83 349,660.40 0.54 1,226.05 MWD+IFR-AK-CAZ-SC(6) 3,294.86 63.22 10.60 2,588.50 2,517.57 1,555.85 146.14 5,967,457.44 349,678.14 0.98 1,289.93 MWD+IFR-AK-CAZ-SC(6) 3,389.84 63.34 11.91 2,631.21 2,560.28 1,639.05 162.69 5,967,540.29 349,696.36 1.24 1,354.67 MWD+IFR-AK-CAZ-SC(6) 3,484.08 63.36 13.32 2,673.48 2,602.55 1,721.24 181.09 5,967,622.09 349,716.39 1.34 1,417.64 MWD+IFR-AK-CAZ-SC(6) 3,578.22 63.29 14.02 2,715.75 2,644.82 1,802.98 200.97 5,967,703.41 349,737.91 0.67 1,479.49 MWD+IFR-AK-CAZ-SC(6) 3,672.82 63.21 13.32 2,758.33 2,687.40 1,885.06 220.93 5,967,785.07 349,759.51 0.67 1,541.60 MWD+IFR-AK-CAZ-SC(6) 3,767.31 63.20 12.01 2,800.92 2,729.99 1,967.35 239.42 5,967,866.96 349,779.65 1.24 1,604.61 MWD+IFR-AK-CAZ-SC(6) 3,861.28 63.17 11.37 2,843.31 2,772.38 2,049.48 256.42 5,967,948.73 349,798.28 0.61 1,668.20 MWD+IFR-AK-CAZ-SC(6) 3,955.76 63.38 11.10 2,885.80 2,814.87 2,132.25 272.86 5,968,031.14 349,816.38 0.34 1,732.62 MWD+IFR-AK-CAZ-SC(6) 4,049.53 63.36 12.41 2,927.84 2,856.91 2,214.31 289.93 5,968,112.84 349,835.09 1.25 1,796.12 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,143.15 63.31 13.77 2,969.85 2,898.92 2,295.80 308.88 5,968,193.93 349,855.67 1.30 1,858.20 MW D+I FR-AK-CAZ-SC(6) 4,236.34 62.87 14.41 3,012.03 2,941.10 2,376.39 329.11 5,968,274.10 349,877.51 0.77 1,918.88 MWD+IFR-AK-CAZ-SC(6) 4,330.40 63.05 13.48 3,054.79 2,983.86 2,457.70 349.30 5,968,354.98 349,899.32 0.90 1,980.21 MWD+IFR-AK-CAZ-SC(6) 4,425.49 62.81 11.86 3,098.07 3,027.14 2,540.31 367.87 5,968,437.19 349,919.54 1.54 2,043.46 MWD+IFR-AK-CAZ-SC(6) 4,519.13 62.92 10.68 3,140.77 3,069.84 2,622.03 384.16 5,968,518.56 349,937.46 1.13 2,107.04 MWD+IFR-AK-CAZ-SC(6) 4,613.19 63.14 10.08 3,183.43 3,112.50 2,704.49 399.26 5,968,600.70 349,954.21 0.61 2,171.84 MWD+IFR-AK-CAZ-SC(6) 4,706.78 63.07 9.44 3,225.77 3,154.84 2,786.75 413.41 5,968,682.65 349,970.01 0.61 2,236.92 MWD+IFR-AK-CAZ-SC(6) 4,801.41 63.04 10.64 3,268.65 3,197.72 2,869.81 428.12 5,968,765.40 349,986.37 1.13 2,302.44 MWD+IFR-AK-CAZ-SC(6) 4,895.24 63.11 12.17 3,311.14 3,240.21 2,951.82 444.66 5,968,847.04 350,004.56 1.46 2,366.14 MWD+IFR-AK-CAZ-SC(6) 4,990.46 62.94 13.50 3,354.34 3,283.41 3,034.55 463.51 5,968,929.38 350,025.06 1.26 2,429.37 MWD+IFR-AK-CAZ-SC(6) 5,084.21 63.08 12.56 3,396.88 3,325.95 3,115.94 482.34 5,969,010.37 350,045.52 0.91 2,491.42 MWD+IFR-AK-CAZ-SC(6) 5,177.74 62.91 14.45 3,439.36 3,368.43 3,196.96 501.80 5,969,090.98 350,066.60 1.81 2,552.85 MW D+I FR-AK-CAZ-SC(6) 5,271.95 63.01 14.28 3,482.18 3,411.25 3,278.25 522.62 5,969,171.83 350,089.04 0.19 2,613.85 MW D+I FR-AK-CAZ-SC(6) 5,365.66 63.01 12.62 3,524.72 3,453.79 3,359.46 542.04 5,969,252.63 350,110.08 1.58 2,675.46 MWD+IFR-AK-CAZ-SC(6) 5,459.19 62.97 10.81 3,567.19 3,496.26 3,441.05 558.96 5,969,333.85 350,128.63 1.72 2,738.62 MWD+IFR-AK-CAZ-SC(6) 5,553.61 63.32 11.12 3,609.85 3,538.92 3,523.75 574.98 5,969,416.21 350,146.31 0.47 2,803.18 MWD+IFR-AK-CAZ-SC(6) 5,647.87 62.93 9.93 3,652.46 3,581.53 3,606.41 590.34 5,969,498.54 350,163.32 1.20 2,868.03 MW D+I FR-AK-CAZ-SC(6) 5,741.96 63.21 8.40 3,695.07 3,624.14 3,689.22 603.70 5,969,581.06 350,178.33 1.48 2,933.99 MWD+IFR-AK-CAZ-SC(6) 5,836.40 63.11 10.71 3,737.72 3,666.79 3,772.31 617.69 5,969,663.85 350,193.98 2.19 2,999.88 MW D+I FR-AK-CAZ-SC(6) 5,930.92 63.05 12.55 3,780.51 3,709.58 3,854.86 634.68 5,969,746.03 350,212.62 1.74 3,063.84 MWD+IFR-AK-CAZ-SC(6) 6,025.42 63.21 12.06 3,823.23 3,752.30 3,937.22 652.64 5,969,828.00 350,232.23 0.49 3,127.16 MWD+IFR-AK-CAZ-SC(6) 6,118.98 63.17 12.69 3,865.42 3,794.49 4,018.78 670.54 5,969,909.19 350,251.75 0.60 3,189.82 MWD+IFR-AK-CAZ-SC(6) 6,212.97 63.14 14.23 3,907.87 3,836.94 4,100.33 690.05 5,969,990.33 350,272.90 1.46 3,251.69 MWD+IFR-AK-CAZ-SC(6) 6,307.33 63.07 13.39 3,950.56 3,879.63 4,182.05 710.14 5,970,071.62 350,294.62 0.80 3,313.42 MWD+IFR-AK-CAZ-SC(6) 6,401.88 63.05 12.47 3,993.39 3,922.46 4,264.20 729.00 5,970,153.37 350,315.12 0.87 3,376.13 MWD+IFR-AK-CAZ-SC(6) 6,495.08 63.07 11.69 4,035.62 3,964.69 4,345.45 746.39 5,970,234.25 350,334.14 0.75 3,438.76 MWD+IFR-AK-CAZ-SC(6) 6,589.70 63.31 10.63 4,078.30 4,007.37 4,428.30 762.73 5,970,316.75 350,352.14 1.03 3,503.30 MWD+IFR-AK-CAZ-SC(6) 6,683.25 63.10 10.57 4,120.47 4,049.54 4,510.38 778.10 5,970,398.50 350,369.14 0.23 3,567.64 MWD+IFR-AK-CAZ-SC(6) 6,778.11 63.28 10.89 4,163.25 4,092.32 4,593.56 793.86 5,970,481.34 350,386.56 0.36 3,632.75 MWD+IFR-AK-CAZ-SC(6) 6,872.00 63.08 12.00 4,205.62 4,134.69 4,675.68 810.48 5,970,563.11 350,404.83 1.08 3,696.52 MW D+I FR-AK-CAZ-SC(6) 6,966.53 63.28 11.56 4,248.27 4,177.34 4,758.27 827.71 5,970,645.32 350,423.70 0.47 3,760.40 MWD+IFR-AK-CAZ-SC(6) 7,061.06 63.17 10.95 4,290.85 4,219.92 4,841.04 844.18 5,970,727.74 350,441.83 0.59 3,824.80 MWD+IFR-AK-CAZ-SC(6) 7,152.64 63.11 10.27 4,332.23 4,261.30 4,921.34 859.22 5,970,807.72 350,458.48 0.67 3,887.74 MWD+IFR-AK-CAZ-SC(6) 7,245.91 63.11 11.41 4,374.41 4,303.48 5,003.04 874.86 5,970,889.08 350,475.75 1.09 3,951.62 MWD+IFR-AK-CAZ-SC(6) 7,340.45 63.04 10.97 4,417.23 4,346.30 5,085.73 891.22 5,970,971.42 350,493.76 0.42 4,016.01 MWD+IFR-AK-CAZ-SC(6) 7,434.38 63.15 11.56 4,459.73 4,388.80 5,167.88 907.59 5,971,053.22 350,511.77 0.57 4,079.92 MWD+IFR-AK-CAZ-SC(6) 7,528.64 63.02 12.13 4,502.40 4,431.47 5,250.14 924.84 5,971,135.11 350,530.67 0.56 4,143.50 MWD+I FR-AK-CAZ-SC(6) 7,623.79 63.05 13.32 4,545.55 4,474.62 5,332.86 943.52 5,971,217.43 350,551.00 1.12 4,206.80 MWD+IFR-AK-CAZ-SC(6) 7,718.35 63.11 14.15 4,588.36 4,517.43 5,414.76 963.54 5,971,298.91 350,572.65 0.79 4,268.72 MWD+IFR-AK-CAZ-SC(6) 7,812.20 63.06 14.00 4,630.84 4,559.91 5,495.93 983.89 5,971,379.65 350,594.63 0.15 4,329.85 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,906.58 63.01 12.84 4,673.64 4,602.71 5,577.75 1,003.41 5,971,461.06 350,615.78 1.10 4,391.95 MWD+IFR-AK-CAZ-SC(6) 8,001.11 62.99 11.73 4,716.55 4,645.62 5,660.05 1,021.33 5,971,542.97 350,635.35 1.05 4,455.24 MWD+IFR-AK-CAZ-SC(6) 8,095.79 62.95 11.47 4,759.58 4,688.65 5,742.66 1,038.29 5,971,625.23 350,653.96 0.25 4,519.27 MWD+IFR-AK-CAZ-SC(6) 8,189.03 63.15 10.62 4,801.84 4,730.91 5,824.24 1,054.21 5,971,706.46 350,671.51 0.84 4,582.90 MWD+IFR-AK-CAZ-SC(6) 8,284.14 63.21 11.40 4,844.75 4,773.82 5,907.55 1,070.42 5,971,789.43 350,689.39 0.73 4,647.91 MWD+IFR-AK-CAZ-SC(6) 8,378.30 63.17 11.91 4,887.22 4,816.29 5,989.86 1,087.40 5,971,871.37 350,708.01 0.49 4,711.67 MWD+IFR-AK-CAZ-SC(6) 8,473.66 63.01 12.94 4,930.38 4,859.45 6,072.90 1,105.69 5,971,954.02 350,727.96 0.98 4,775.43 MWD+IFR-AK-CAZ-SC(6) 8,568.33 63.18 12.37 4,973.22 4,902.29 6,155.27 1,124.19 5,972,036.00 350,748.10 0.57 4,838.50 MWD+IFR-AK-CAZ-SC(6) 8,662.37 62.94 14.00 5,015.83 4,944.90 6,236.89 1,143.31 5,972,117.21 350,768.85 1.57 4,900.62 MWD+IFR-AK-CAZ-SC(6) 8,757.47 63.02 13.62 5,059.03 4,988.10 6,319.16 1,163.53 5,972,199.06 350,790.72 0.37 4,962.77 MWD+IFR-AK-CAZ-SC(6) 8,850.32 62.81 13.05 5,101.31 5,030.38 6,399.60 1,182.60 5,972,279.09 350,811.39 0.59 5,023.88 MWD+IFR-AK-CAZ-SC(6) 8,942.87 63.22 13.04 5,143.31 5,072.38 6,479.95 1,201.21 5,972,359.04 350,831.62 0.44 5,085.13 MWD+IFR-AK-CAZ-SC(6) 9,037.33 62.98 13.61 5,186.04 5,115.11 6,561.92 1,220.63 5,972,440.60 350,852.67 0.60 5,147.41 MWD+IFR-AK-CAZ-SC(6) 9,130.73 63.03 13.66 5,228.44 5,157.51 6,642.79 1,240.25 5,972,521.06 350,873.90 0.07 5,208.63 MWD+IFR-AK-CAZ-SC(6) 9,224.56 62.82 13.68 5,271.15 5,200.22 6,723.97 1,259.99 5,972,601.82 350,895.27 0.22 5,270.06 MWD+IFR-AK-CAZ-SC(6) 9,318.28 62.79 14.34 5,313.98 5,243.05 6,804.85 1,280.17 5,972,682.28 350,917.06 0.63 5,331.02 MWD+IFR-AK-CAZ-SC(6) 9,413.52 63.00 13.23 5,357.37 5,286.44 6,887.19 1,300.37 5,972,764.19 350,938.91 1.06 5,393.24 MWD+IFR-AK-CAZ-SC(6) 9,505.61 62.93 12.09 5,399.23 5,328.30 6,967.22 1,318.35 5,972,843.83 350,958.49 1.11 5,454.52 MWD+IFR-AK-CAZ-SC(6) 9,599.57 63.61 10.72 5,441.50 5,370.57 7,049.48 1,334.94 5,972,925.74 350,976.72 1.49 5,518.42 MWD+IFR-AK-CAZ-SC(6) 9,694.49 63.42 11.25 5,483.83 5,412.90 7,132.88 1,351.13 5,973,008.79 350,994.58 0.54 5,583.52 MWD+IFR-AK-CAZ-SC(6) 9,788.74 63.36 10.30 5,526.04 5,455.11 7,215.66 1,366.88 5,973,091.23 351,011.98 0.90 5,648.28 MWD+IFR-AK-CAZ-SC(6) 9,883.29 63.45 10.34 5,568.37 5,497.44 7,298.84 1,382.03 5,973,174.08 351,028.79 0.10 5,713.69 MWD+IFR-AK-CAZ-SC(6) 9,977.52 62.93 10.48 5,610.87 5,539.94 7,381.56 1,397.23 5,973,256.47 351,045.64 0.57 5,778.67 MWD+IFR-AK-CAZ-SC(6) 10,071.11 63.47 11.53 5,653.07 5,582.14 7,463.56 1,413.17 5,973,338.13 351,063.23 1.16 5,842.65 MWD+IFR-AK-CAZ-SC(6) 10,165.79 62.54 12.25 5,696.05 5,625.12 7,546.11 1,430.55 5,973,420.31 351,082.26 1.19 5,906.43 MWD+IFR-AK-CAZ-SC(6) 10,260.40 62.93 12.52 5,739.39 5,668.46 7,628.25 1,448.59 5,973,502.07 351,101.94 0.48 5,969.53 MWD+IFR-AK-CAZ-SC(6) 10,355.00 63.02 13.29 5,782.37 5,711.44 7,710.39 1,467.41 5,973,583.81 351,122.40 0.73 6,032.24 MWD+IFR-AK-CAZ-SC(6) 10,448.49 62.67 12.54 5,825.04 5,754.11 7,791.47 1,486.00 5,973,664.50 351,142.61 0.81 6,094.14 MWD+IFR-AK-CAZ-SC(6) 10,542.00 63.23 11.91 5,867.57 5,796.64 7,872.86 1,503.64 5,973,745.51 351,161.87 0.85 6,156.78 MWD+IFR-AK-CAZ-SC(6) 10,635.69 63.12 11.90 5,909.85 5,838.92 7,954.67 1,520.89 5,973,826.95 351,180.76 0.12 6,219.97 MWD+IFR-AK-CAZ-SC(6) 10,729.09 63.01 11.68 5,952.16 5,881.23 8,036.18 1,537.90 5,973,908.10 351,199.40 0.24 6,283.02 MWD+IFR-AK-CAZ-SC(6) 10,822.63 63.33 11.26 5,994.37 5,923.44 8,117.99 1,554.50 5,973,989.55 351,217.63 0.53 6,346.52 MWD+IFR-AK-CAZ-SC(6) 10,916.45 63.00 11.60 6,036.73 5,965.80 8,200.04 1,571.09 5,974,071.25 351,235.86 0.48 6,410.24 MWD+IFR-AK-CAZ-SC(6) 11,009.82 63.07 11.26 6,079.07 6,008.14 8,281.61 1,587.58 5,974,152.46 351,253.98 0.33 6,473.59 MWD+IFR-AK-CAZ-SC(6) 11,104.11 63.28 11.03 6,121.62 6,050.69 8,364.17 1,603.84 5,974,234.67 351,271.90 0.31 6,537.91 MWD+IFR-AK-CAZ-SC(6) 11,196.28 63.31 11.83 6,163.04 6,092.11 8,444.87 1,620.16 5,974,315.03 351,289.83 0.78 6,600.58 MWD+IFR-AK-CAZ-SC(6) 11,291.67 62.94 12.01 6,206.16 6,135.23 8,528.12 1,637.73 5,974,397.91 351,309.07 0.42 6,664.88 MWD+IFR-AK-CAZ-SC(6) 11,390.45 63.30 12.57 6,250.82 6,179.89 8,614.21 1,656.49 5,974,483.59 351,329.54 0.62 6,731.08 MWD+IFR-AK-CAZ-SC(6) 11,478.46 62.91 12.77 6,290.63 6,219.70 8,690.79 1,673.70 5,974,559.81 351,348.29 0.49 6,789.71 MWD+IFR-AK-CAZ-SC(6) 11,572.12 63.15 13.21 6,333.11 6,262.18 8,772.13 1,692.47 5,974,640.74 351,368.68 0.49 6,851.75 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,666.71 63.12 13.25 6,375.85 6,304.92 8,854.27 1,711.78 5,974,722.48 351,389.63 0.05 6,914.23 MWD+IFR-AK-CAZ-SC(6) 11,760.40 63.04 12.17 6,418.27 6,347.34 8,935.76 1,730.16 5,974,803.58 351,409.64 1.03 6,976.59 MWD+IFR-AK-CAZ-SC(6) 11,854.28 63.09 11.07 6,460.80 6,389.87 9,017.74 1,747.02 5,974,885.19 351,428.13 1.05 7,040.12 MWD+IFR-AK-CAZ-SC(6) 11,949.26 62.98 11.98 6,503.87 6,432.94 9,100.68 1,763.93 5,974,967.78 351,446.70 0.86 7,104.47 MWD+IFR-AK-CAZ-SC(6) 12,041.95 63.26 12.06 6,545.77 6,474.84 9,181.55 1,781.15 5,975,048.27 351,465.54 0.31 7,166.84 MWD+IFR-AK-CAZ-SC(6) 12,135.18 63.25 12.35 6,587.73 6,516.80 9,262.92 1,798.75 5,975,129.27 351,484.76 0.28 7,229.48 MWD+IFR-AK-CAZ-SC(6) 12,228.87 62.94 13.17 6,630.13 6,559.20 9,344.40 1,817.20 5,975,210.36 351,504.84 0.85 7,291.80 MWD+IFR-AK-CAZ-SC(6) 12,322.52 63.31 12.62 6,672.46 6,601.53 9,425.83 1,835.84 5,975,291.40 351,525.11 0.66 7,353.99 MWD+IFR-AK-CAZ-SC(6) 12,417.38 63.05 11.60 6,715.26 6,644.33 9,508.60 1,853.60 5,975,373.79 351,544.53 1.00 7,417.77 MWD+IFR-AK-CAZ-SC(6) 12,510.87 63.02 11.00 6,757.65 6,686.72 9,590.31 1,869.93 5,975,455.15 351,562.49 0.57 7,481.32 MWD+IFR-AK-CAZ-SC(6) 12,603.06 63.12 11.24 6,799.41 6,728.48 9,670.96 1,885.78 5,975,535.46 351,579.95 0.26 7,544.17 MWD+IFR-AK-CAZ-SC(6) 12,697.18 62.84 10.81 6,842.17 6,771.24 9,753.26 1,901.82 5,975,617.41 351,597.63 0.50 7,608.38 MWD+IFR-AK-CAZ-SC(6) 12,790.91 63.09 10.44 6,884.77 6,813.84 9,835.32 1,917.21 5,975,699.14 351,614.66 0.44 7,672.68 MWD+IFR-AK-CAZ-SC(6) 12,884.80 63.17 10.47 6,927.20 6,856.27 9,917.68 1,932.41 5,975,781.17 351,631.51 0.09 7,737.35 MWD+IFR-AK-CAZ-SC(6) 12,978.94 63.08 10.31 6,969.76 6,898.83 10,000.28 1,947.55 5,975,863.44 351,648.30 0.18 7,802.25 MWD+IFR-AK-CAZ-SC(6) 13,072.28 63.13 10.29 7,011.98 6,941.05 10,082.18 1,962.44 5,975,945.02 351,664.83 0.06 7,866.66 MWD+IFR-AK-CAZ-SC(6) 13,166.26 63.71 9.53 7,054.03 6,983.10 10,164.97 1,976.90 5,976,027.50 351,680.94 0.95 7,932.06 MWD+IFR-AK-CAZ-SC(6) 13,259.54 65.07 6.32 7,094.36 7,023.43 10,248.27 1,988.48 5,976,110.55 351,694.19 3.43 7,999.30 MWD+IFR-AK-CAZ-SC(6) 13,353.66 65.36 3.42 7,133.82 7,062.89 10,333.40 1,995.73 5,976,195.51 351,703.15 2.81 8,070.24 MWD+IFR-AK-CAZ-SC(6) 13,447.09 65.82 1.29 7,172.44 7,101.51 10,418.40 1,999.22 5,976,280.41 351,708.34 2.13 8,142.89 MWD+IFR-AK-CAZ-SC(6) 13,540.30 67.13 359.30 7,209.65 7,138.72 10,503.85 1,999.66 5,976,365.84 351,710.49 2.41 8,217.42 MWD+IFR-AK-CAZ-SC(6) 13,634.11 69.29 356.39 7,244.47 7,173.54 10,590.88 1,996.37 5,976,452.91 351,708.94 3.69 8,295.14 MWD+IFR-AK-CAZ-SC(6) 13,727.73 71.67 354.23 7,275.76 7,204.83 10,678.81 1,989.14 5,976,540.96 351,703.48 3.35 8,375.54 MWD+IFR-AK-CAZ-SC(6) 13,821.63 73.64 352.97 7,303.75 7,232.82 10,767.87 1,979.14 5,976,630.20 351,695.27 2.46 8,458.29 MWD+IFR-AK-CAZ-SC(6) 13,915.09 74.45 351.64 7,329.44 7,258.51 10,856.92 1,967.11 5,976,719.46 351,685.03 1.62 8,542.00 MWD+IFR-AK-CAZ-SC(6) 14,008.99 77.21 349.76 7,352.43 7,281.50 10,946.75 1,952.39 5,976,809.56 351,672.11 3.52 8,627.71 MWD+IFR-AK-CAZ-SC(6) 14,102.96 79.55 346.72 7,371.36 7,300.43 11,036.85 1,933.62 5,976,900.01 351,655.16 4.03 8,715.60 MWD+IFR-AK-CAZ-SC(6) 14,196.39 82.58 343.00 7,385.87 7,314.94 11,125.91 1,909.51 5,976,989.53 351,632.84 5.10 8,805.19 MWD+IFR-AK-CAZ-SC(6) 14,290.68 85.43 340.62 7,395.72 7,324.79 11,214.98 1,880.24 5,977,079.16 351,605.36 3.93 8,897.28 MWD+IFR-AK-CAZ-SC(6) 14,340.65 86.94 338.69 7,399.04 7,328.11 11,261.72 1,862.90 5,977,126.24 351,588.96 4.91 8,946.57 N NOT an Actual Survey (6) 7-5/8"x 9-7/8"by 11" 14,385.36 88.30 336.96 7,400.90 7,329.97 11,303.09 1,846.04 5,977,167.93 351,572.94 4.91 8,990.92 MWD+IFR-AK-CAZ-SC(6) 14,418.67 89.04 335.19 7,401.67 7,330.74 11,333.53 1,832.54 5,977,198.63 351,560.05 5.76 9,024.09 MWD+IFR-AK-CAZ-SC(6) 14,514.76 91.30 330.78 7,401.39 7,330.46 11,419.10 1,788.91 5,977,285.06 351,518.14 5.16 9,120.09 MWD+IFR-AK-CAZ-SC(6) 14,608.02 90.79 329.62 7,399.69 7,328.76 11,500.02 1,742.57 5,977,366.88 351,473.44 1.36 9,213.33 MWD+IFR-AK-CAZ-SC(6) 14,704.29 91.55 327.85 7,397.72 7,326.79 11,582.29 1,692.62 5,977,450.13 351,425.15 2.00 9,309.50 MWD+IFR-AK-CAZ-SC(6) 14,798.61 91.64 326.93 7,395.10 7,324.17 11,661.71 1,641.81 5,977,530.54 351,375.94 0.98 9,403.59 MWD+IFR-AK-CAZ-SC(6) 14,893.77 91.57 326.08 7,392.43 7,321.50 11,741.03 1,589.31 5,977,610.90 351,325.05 0.90 9,498.42 MWD+IFR-AK-CAZ-SC(6) 14,988.78 91.63 326.49 7,389.78 7,318.85 11,820.03 1,536.60 5,977,690.93 351,273.93 0.44 9,593.07 MWD+IFR-AK-CAZ-SC(6) 15,084.07 90.06 325.97 7,388.37 7,317.44 11,899.23 1,483.64 5,977,771.17 351,222.58 1.74 9,688.02 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 6 COMPASS 5000.1 Build 74 • i Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 15,180.90 90.24 325.84 7,388.12 7,317.19 11,979.42 1,429.36 5,977,852.42 351,169.92 0.23 9,784.47 MWD+IFR-AK-CAZ-SC(6) 15,275.81 90.42 326.79 7,387.57 7,316.64 12,058.39 1,376.72 5,977,932.43 351,118.88 1.02 9,879.06 MW D+I FR-AK-CAZ-SC(6) 15,370.39 89.62 327.37 7,387.54 7,316.61 12,137.78 1,325.32 5,978,012.83 351,069.08 1.04 9,973.42 MW D+I FR-AK-CAZ-SC(6) 15,465.39 89.31 330.83 7,388.43 7,317.50 12,219.28 1,276.54 5,978,095.29 351,021.95 3.66 10,068.34 MWD+1FR-AK-CAZ-SC(6) 15,561.80 89.35 334.66 7,389.55 7,318.62 12,304.97 1,232.40 5,978,181.83 350,979.54 3.97 10,164.69 MWD+IFR-AK-CAZ-SC(6) 15,656.70 89.69 336.14 7,390.35 7,319.42 12,391.25 1,192.90 5,978,268.88 350,941.78 1.60 10,259.30 MWD+IFR-AK-CAZ-SC(6) 15,752.09 89.65 335.78 7,390.90 7,319.97 12,478.36 1,154.04 5,978,356.75 350,904.68 0.38 10,354.33 MW D+I FR-AK-CAZ-SC(6) 15,848.54 89.76 334.42 7,391.40 7,320.47 12,565.84 1,113.43 5,978,445.02 350,865.83 1.41 10,450.53 MWD+IFR-AK-CAZ-SC(6) 15,944.42 89.77 334.75 7,391.79 7,320.86 12,652.44 1,072.28 5,978,532.42 350,826.43 0.34 10,546.22 MWD+IFR-AK-CAZ-SC(6) 16,039.41 88.83 335.18 7,392.95 7,322.02 12,738.50 1,032.09 5,978,619.26 350,787.98 1.09 10,640.98 MWD+IFR-AK-CAZ-SC(6) 16,135.23 88.80 335.25 7,394.93 7,324.00 12,825.48 991.93 5,978,707.02 350,749.57 0.08 10,736.52 MWD+IFR-AK-CAZ-SC(6) 16,230.34 89.84 333.71 7,396.06 7,325.13 12,911.30 950.96 5,978,793.64 350,710.33 1.95 10,831.44 MWD+IFR-AK-CAZ-SC(6) 16,325.78 89.93 333.41 7,396.25 7,325.32 12,996.75 908.46 5,978,879.92 350,669.56 0.33 10,926.78 MWD+IFR-AK-CAZ-SC(6) 16,419.08 90.79 332.71 7,395.66 7,324.73 13,079.92 866.19 5,978,963.92 350,628.97 1.19 11,020.02 MWD+IFR-AK-CAZ-SC(6) 16,514.32 91.23 332.81 7,393.99 7,323.06 13,164.59 822.61 5,979,049.43 350,587.09 0.47 11,115.20 MWD+IFR-AK-CAZ-SC(6) 16,609.87 91.20 332.59 7,391.96 7,321.03 13,249.48 778.79 5,979,135.18 350,544.99 0.23 11,210.69 MWD+IFR-AK-CAZ-SC(6) 16,705.02 91.23 331.55 7,389.94 7,319.01 13,333.52 734.24 5,979,220.09 350,502.13 1.09 11,305.80 MWD+IFR-AK-CAZ-SC(6) 16,801.11 91.34 331.58 7,387.79 7,316.86 13,418.00 688.49 5,979,305.46 350,458.09 0.12 11,401.86 MWD+I FR-AK-CAZ-SC(6) 16,896.86 90.85 330.99 7,385.96 7,315.03 13,501.96 642.50 5,979,390.32 350,413.79 0.80 11,497.59 MWD+IFR-AK-CAZ-SC(6) 16,991.58 90.00 331.09 7,385.25 7,314.32 13,584.83 596.64 5,979,474.09 350,369.61 0.90 11,592.31 MWD+IFR-AK-CAZ-SC(6) 17,087.48 89.89 330.24 7,385.35 7,314.42 13,668.43 549.66 5,979,558.61 350,324.31 0.89 11,688.20 MWD+IFR-AK-CAZ-SC(6) 17,184.52 90.17 330.30 7,385.30 7,314.37 13,752.70 501.53 5,979,643.82 350,277.89 0.30 11,785.24 MWD+IFR-AK-CAZ-SC(6) 17,278.91 90.80 331.06 7,384.50 7,313.57 13,835.00 455.31 5,979,727.02 350,233.33 1.05 11,879.62 MWD+IFR-AK-CAZ-SC(6) 17,373.47 90.85 331.69 7,383.14 7,312.21 13,917.99 410.02 5,979,810.89 350,189.71 0.67 11,974.17 MWD+IFR-AK-CAZ-SC(6) 17,469.08 90.34 331.37 7,382.14 7,311.21 14,002.03 364.44 5,979,895.83 350,145.84 0.63 12,069.77 MWD+IFR-AK-CAZ-SC(6) 17,563.66 90.41 332.64 7,381.52 7,310.59 14,085.54 320.05 5,979,980.20 350,103.13 1.34 12,164.33 MWD+IFR-AK-CAZ-SC(6) 17,659.45 90.44 333.60 7,380.81 7,309.88 14,170.98 276.74 5,980,066.48 350,061.55 1.00 12,260.05 MWD+IFR-AK-CAZ-SC(6) 17,753.82 90.34 334.97 7,380.17 7,309.24 14,256.00 235.80 5,980,152.30 350,022.32 1.46 12,354.26 MWD+IFR-AK-CAZ-SC(6) 17,849.43 90.37 335.22 7,379.58 7,308.65 14,342.72 195.53 5,980,239.80 349,983.80 0.26 12,449.62 MWD+IFR-AK-CAZ-SC(6) 17,944.77 90.34 335.47 7,378.99 7,308.06 14,429.36 155.76 5,980,327.22 349,945.78 0.26 12,544.69 MWD+IFR-AK-CAZ-SC(6) 18,040.83 90.27 335.89 7,378.48 7,307.55 14,516.90 116.20 5,980,415.52 349,907.99 0.44 12,640.43 MWD+IFR-AK-CAZ-SC(6) 18,134.93 90.00 336.02 7,378.25 7,307.32 14,602.83 77.86 5,980,502.20 349,871.38 0.32 12,734.17 MWD+IFR-AK-CAZ-SC(6) 18,230.43 89.41 335.35 7,378.75 7,307.82 14,689.86 38.54 5,980,589.99 349,833.81 0.93 12,829.35 MWD+IFR-AK-CAZ-SC(6) 18,325.63 88.87 334.66 7,380.18 7,309.25 14,776.13 -1.68 5,980,677.05 349,795.33 0.92 12,924.31 MWD+IFR-AK-CAZ-SC(6) 18,421.05 88.42 334.65 7,382.43 7,311.50 14,862.34 -42.51 5,980,764.06 349,756.23 0.47 13,019.51 MWD+IFR-AK-CAZ-SC(6) 18,515.56 87.84 333.91 7,385.52 7,314.59 14,947.44 -83.51 5,980,849.95 349,716.96 0.99 13,113.81 MWD+IFR-AK-CAZ-SC(6) 18,612.05 87.32 333.45 7,389.59 7,318.66 15,033.85 -126.25 5,980,937.20 349,675.96 0.72 13,210.11 MWD+IFR-AK-CAZ-SC(6) 18,708.10 86.70 333.00 7,394.60 7,323.67 15,119.49 -169.46 5,981,023.67 349,634.48 0.80 13,305.96 MWD+IFR-AK-CAZ-SC(6) 18,802.30 88.73 333.65 7,398.36 7,327.43 15,203.59 -211.71 5,981,108.60 349,593.92 2.26 13,400.00 MWD+IFR-AK-CAZ-SC(6) 18,891.28 92.08 332.15 7,397.73 7,326.80 15,282.78 -252.24 5,981,188.59 349,554.99 4.12 13,488.91 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 2:58:02PM Page 7 COMPASS 5000.1 Build 74 s • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 18,988.75 94.04 331.45 7,392.52 7,321.59 15,368.56 -298.23 5,981,275.26 349,510.73 2.13 13,586.23 MWD+IFR-AK-CAZ-SC(6) 19,087.81 94.15 330.07 7,385.45 7,314.52 15,454.77 -346.49 5,981,362.42 349,464.21 1.39 13,685.03 MWD+IFR-AK-CAZ-SC(6) 19,183.81 94.22 328.41 7,378.44 7,307.51 15,537.04 -395.46 5,981,445.65 349,416.91 1.73 13,780.73 MWD+IFR-AK-CAZ-SC(6) 19,278.08 94.18 328.83 7,371.54 7,300.61 15,617.31 -444.41 5,981,526.87 349,369.58 0.45 13,874.66 MWD+IFR-AK-CAZ-SC(6) 19,372.36 94.15 328.37 7,364.69 7,293.76 15,697.57 -493.41 5,981,608.09 349,322.21 0.49 13,968.61 MWD+IFR-AK-CAZ-SC(6) 19,468.80 93.99 328.43 7,357.85 7,286.92 15,779.50 -543.81 5,981,691.01 349,273.46 0.18 14,064.71 MWD+IFR-AK-CAZ-SC(6) 19,563.70 93.15 327.57 7,351.94 7,281.01 15,859.82 -594.00 5,981,772.32 349,224.89 1.27 14,159.29 MWD+IFR-AK-CAZ-SC(6) 19,659.57 93.21 329.81 7,346.62 7,275.69 15,941.60 -643.74 5,981,855.07 349,176.80 2.33 14,254.93 MWD+IFR-AK-CAZ-SC(6) 19,753.65 92.02 329.85 7,342.33 7,271.40 16,022.85 -690.97 5,981,937.24 349,131.21 1.27 14,348.89 MWD+IFR-AK-CAZ-SC(6) 19,849.98 91.13 331.05 7,339.68 7,268.75 16,106.62 -738.46 5,982,021.94 349,085.42 1.55 14,445.18 MWD+IFR-AK-CAZ-SC(6) 19,945.55 90.13 329.96 7,338.63 7,267.70 16,189.79 -785.51 5,982,106.04 349,040.05 1.55 14,540.74 MWD+IFR-AK-CAZ-SC(6) 20,040.96 90.06 330.35 7,338.47 7,267.54 16,272.55 -832.99 5,982,189.72 348,994.24 0.42 14,636.14 MWD+IFR-AK-CAZ-SC(6) 20,135.12 90.13 331.41 7,338.31 7,267.38 16,354.81 -878.82 5,982,272.87 348,950.08 1.13 14,730.29 MWD+IFR-AK-CAZ-SC(6) 20,231.42 90.10 330.96 7,338.12 7,267.19 16,439.18 -925.23 5,982,358.16 348,905.37 0.47 14,826.59 MWD+IFR-AK-CAZ-SC(6) 20,326.61 90.13 332.00 7,337.93 7,267.00 16,522.82 -970.68 5,982,442.68 348,861.60 1.09 14,921.78 MWD+IFR-AK-CAZ-SC(6) 20,421.08 90.03 332.62 7,337.80 7,266.87 16,606.47 -1,014.58 5,982,527.19 348,819.39 0.66 15,016.22 MWD+IFR-AK-CAZ-SC(6) 20,516.76 90.59 333.38 7,337.28 7,266.35 16,691.72 -1,058.02 5,982,613.28 348,777.68 0.99 15,111.84 MWD+IFR-AK-CAZ-SC(6) 20,613.10 90.65 333.89 7,336.24 7,265.31 16,778.03 -1,100.80 5,982,700.43 348,736.64 0.53 15,208.07 MWD+IFR-AK-CAZ-SC(6) 20,707.11 90.58 332.93 7,335.23 7,264.30 16,862.09 -1,142.87 5,982,785.31 348,696.26 1.02 15,302.00 MWD+IFR-AK-CAZ-SC(6) 20,802.44 90.58 333.31 7,334.26 7,263.33 16,947.12 -1,185.97 5,982,871.18 348,654.88 0.40 15,397.25 MWD+IFR-AK-CAZ-SC(6) 20,898.28 90.65 334.48 7,333.23 7,262.30 17,033.18 -1,228.14 5,982,958.06 348,614.45 1.22 15,492.97 MWD+IFR-AK-CAZ-SC(6) 20,939.03 90.72 333.72 7,332.75 7,261.82 17,069.83 -1,245.94 5,982,995.06 348,597.39 1.87 15,533.65 MWD+IFR-AK-CAZ-SC(6) 20,990.00 90.72 333.72 7,332.11 7,261.18 17,115.53 -1,268.50 5,983,041.20 348,575.74 0.00 15,584.56 NOT an Actual Survey 4-1/2"x 6-1/2" 20,999.00 90.72 333.72 7,331.99 7,261.06 17,123.60 -1,272.49 5,983,049.34 348,571.92 0.00 15,593.55 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. [j Yes ❑ No 1 have checked to the best of my ability that the following data is correct: Q Surface Coordinates p Declination & Convergence [J GRS Survey Corrections El Survey Tool Codes Vincent Digitally signed byvi.[e4 onn DK 131=VIIKINIt mark t. �.ou=�. SLB DE: OSd ra m,s"°;11 1 .44_ 1.15 Weifeng Dal Client Representative: Date: 24-Nov-2015 11/30/2015 2:58:02PM Page 8 COMPASS 5000.1 Build 74 • • • 215146 6497 REVISED 3:22 pm, Dec 03, 2015 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-03 Definitive Survey Report 30 November, 2015 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD5-03 Well Position +N/-S 0.00 usft Northing: 5,965,650.92 usfl Latitude: 70°18'49.042 N +E/-W 0.00 usft Easting: 1,489,534.00 usft Longitude: 151°13'22.493 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 34.10 usft Wellbore CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGG M2015 11/6/2015 17.93 80.83 57,471 Design CD5-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.83 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.83 0.00 0.00 331.00 Survey Program Date 11/30/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 109.00 640.00 CD5-03 Svy1 -SLB_NSG+SSHOT(CD5 GYD-GC-SS Gyrodata gyro single shots 10/20/2015 9:: 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:• 2,393.84 2,393.84 CD5-03 Svy3-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 2,446.61 3,012.81 CD5-03 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1: 3,107.13 3,107.13 CD5-03 Svy5-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 3,201.32 20,939.03 CD5-03 Svy6-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -34.10 0.00 0.00 5,965,650.92 1,489,534.00 0.00 0.00 UNDEFINED 109.00 0.41 157.11 109.00 38.07 -0.24 0.10 5,965,650.68 1,489,534.10 0.57 -0.26 GYD-GC-SS(1) 115.00 0.41 160.09 115.00 44.07 -0.28 0.12 5,965,650.64 1,489,534.11 0.36 -0.30 (NOT an Actual Survey 20"x42" 181.00 0.49 188.69 181.00 110.07 -0.78 0.15 5,965,650.14 1,489,534.14 0.36 -0.76 GYD-GC-SS(1) 286.00 0.46 171.22 285.99 215.06 -1.64 0.15 5,965,649.28 1,489,534.12 0.14 -1.51 GYD-GC-SS(1) 379.00 0.40 315.40 378.99 308.06 -1.78 -0.02 5,965,649.14 1,489,533.94 0.88 -1.54 GYD-GC-SS(1) 456.00 1.32 332.42 455.98 385.05 -0.80 -0.62 5,965,650.13 1,489,533.36 1.23 -0.40 GYD-GC-SS(1) 547.00 3.64 342.74 546.89 475.96 2.89 -1.96 5,965,653.85 1,489,532.10 2.59 3.48 GYD-GC-SS(1) 640.00 5.10 341.44 639.62 568.69 9.63 -4.15 5,965,660.63 1,489,530.04 1.57 10.43 GYD-GC-SS(1) 11/30/2015 11:49:23AM Page 2 COMPASS 5000.1 Build 74 i • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 706.73 6.66 341.30 706.00 635.07 16.10 -6.34 5,965,667.15 1,489,527.99 2.34 17.16 MWD+IFR-AK-CAZ-SC(2) 763.64 9.05 346.48 762.37 691.44 23.58 -8.44 5,965,674.67 1,489,526.03 4.38 24.72 MWD+IFR-AK-CAZ-SC(2) 857.86 10.91 350.45 855.16 784.23 39.58 -11.66 5,965,690.73 1,489,523.14 2.10 40.27 MWD+IFR-AK-CAZ-SC(2) 952.85 13.26 350.82 948.04 877.11 59.20 -14.89 5,965,710.41 1,489,520.31 2.48 59.00 MWD+IFR-AK-CAZ-SC(2) 1,046.87 16.13 351.66 1,038.97 968.04 82.78 -18.50 5,965,734.04 1,489,517.17 3.06 81.37 MWD+IFR-AK-CAZ-SC(2) 1,139.96 18.17 352.74 1,127.92 1,056.99 109.97 -22.21 5,965,761.31 1,489,514.00 2.22 106.95 MWD+IFR-AK-CAZ-SC(2) 1,234.44 19.22 353.12 1,217.41 1,146.48 140.02 -25.94 5,965,791.43 1,489,510.89 1.12 135.04 MWD+IFR-AK-CAZ-SC(2) 1,329.46 21.62 352.72 1,306.46 1,235.53 172.92 -30.03 5,965,824.40 1,489,507.45 2.53 165.80 MWD+IFR-AK-CAZ-SC(2) 1,423.98 22.55 352.28 1,394.04 1,323.11 208.15 -34.67 5,965,859.71 1,489,503.52 1.00 198.86 MWD+IFR-AK-CAZ-SC(2) 1,518.01 23.21 353.74 1,480.67 1,409.74 244.44 -39.11 5,965,896.08 1,489,499.81 0.93 232.75 MWD+IFR-AK-CAZ-SC(2) 1,612.52 26.26 355.12 1,566.50 1,495.57 283.79 -42.92 5,965,935.50 1,489,496.79 3.28 269.02 MWD+IFR-AK-CAZ-SC(2) 1,705.02 29.72 357.69 1,648.17 1,577.24 327.11 -45.59 5,965,978.85 1,489,495.00 3.96 308.19 MWD+IFR-AK-CAZ-SC(2) 1,799.69 33.51 1.37 1,728.79 1,657.86 376.70 -45.91 5,966,028.44 1,489,495.67 4.49 351.73 MWD+IFR-AK-CAZ-SC(2) 1,893.56 36.33 2.16 1,805.75 1,734.82 430.40 -44.24 5,966,082.09 1,489,498.42 3.04 397.89 MWD+IFR-AK-CAZ-SC(2) 1,987.71 39.54 2.93 1,879.99 1,809.06 488.22 -41.66 5,966,139.84 1,489,502.16 3.45 447.20 MWD+IFR-AK-CAZ-SC(2) 2,082.01 42.89 4.47 1,950.92 1,879.99 550.21 -37.62 5,966,201.73 1,489,507.45 3.71 499.46 MWD+IFR-AK-CAZ-SC(2) 2,175.54 46.13 7.05 2,017.62 1,946.69 615.42 -31.00 5,966,266.79 1,489,515.37 3.97 553.29 MWD+IFR-AK-CAZ-SC(2) 2,270.65 49.64 7.72 2,081.39 2,010.46 685.37 -21.92 5,966,336.54 1,489,525.86 3.73 610.07 MWD+IFR-AK-CAZ-SC(2) 2,332.23 52.58 9.87 2,120.05 2,049.12 732.73 -14.58 5,966,383.74 1,489,534.15 5.49 647.92 MWD+IFR-AK-CAZ-SC(2) 2,393.40 53.25 9.01 2,156.94 2,086.01 780.86 -6.58 5,966,431.70 1,489,543.12 1.57 686.15 NOTanActualSurvey 10-3/4"x 13-1/2" 2,393.84 53.25 9.00 2,157.20 2,086.27 781.21 -6.52 5,966,432.05 1,489,543.18 1.57 686.42 INC+TREND(3) 2,446.61 54.40 8.42 2,188.35 2,117.42 823.32 -0.07 5,966,474.01 1,489,550.47 2.35 720.12 MWD+IFR-AK-CAZ-SC(4) 2,540.41 58.16 9.29 2,240.41 2,169.48 900.39 11.95 5,966,550.82 1,489,564.04 4.08 781.70 MWD+IFR-AK-CAZ-SC(4) 2,635.46 61.10 10.07 2,288.46 2,217.53 981.22 25.74 5,966,631.35 1,489,579.45 3.17 845.71 MWD+IFR-AK-CAZ-SC(4) 2,729.01 62.78 12.72 2,332.47 2,261.54 1,062.13 42.07 5,966,711.91 1,489,597.40 3.08 908.56 MWD+IFR-AK-CAZ-SC(4) 2,823.37 63.11 13.13 2,375.39 2,304.46 1,144.03 60.86 5,966,793.41 1,489,617.83 0.52 971.09 MWD+IFR-AK-CAZ-SC(4) 2,918.15 62.77 12.29 2,418.51 2,347.58 1,226.37 79.43 5,966,875.35 1,489,638.05 0.87 1,034.09 MWD+IFR-AK-CAZ-SC(4) 3,012.81 63.22 11.64 2,461.49 2,390.56 1,308.87 96.92 5,966,957.48 1,489,657.19 0.77 1,097.78 MWD+IFR-AK-CAZ-SC(4) 3,107.13 63.22 11.06 2,503.99 2,433.06 1,391.43 113.49 5,967,039.68 1,489,675.42 0.55 1,161.95 INC+TREND(5) 3,201.32 63.27 11.63 2,546.39 2,475.46 1,473.89 130.03 5,967,121.79 1,489,693.61 0.54 1,226.05 MWD+IFR-AK-CAZ-SC(6) 3,294.86 63.22 10.60 2,588.50 2,517.57 1,555.85 146.14 5,967,203.40 1,489,711.36 0.98 1,289.93 MWD+IFR-AK-CAZ-SC(6) 3,389.84 63.34 11.91 2,631.21 2,560.28 1,639.05 162.69 5,967,286.25 1,489,729.58 1.24 1,354.67 MWD+IFR-AK-CAZ-SC(6) 3,484.08 63.36 13.32 2,673.48 2,602.55 1,721.24 181.09 5,967,368.05 1,489,749.63 1.34 1,417.64 MWD+IFR-AK-CAZ-SC(6) 3,578.22 63.29 14.02 2,715.75 2,644.82 1,802.98 200.97 5,967,449.36 1,489,771.14 0.67 1,479.49 MWD+IFR-AK-CAZ-SC(6) 3,672.82 63.21 13.32 2,758.33 2,687.40 1,885.06 220.93 5,967,531.02 1,489,792.75 0.67 1,541.60 MWD+IFR-AK-CAZ-SC(6) 3,767.31 63.20 12.01 2,800.92 2,729.99 1,967.35 239.42 5,967,612.92 1,489,812.89 1.24 1,604.61 MWD+IFR-AK-CAZ-SC(6) 3,861.28 63.17 11.37 2,843.31 2,772.38 2,049.48 256.42 5,967,694.68 1,489,831.53 0.61 1,668.20 MWD+IFR-AK-CAZ-SC(6) 3,955.76 63.38 11.10 2,885.80 2,814.87 2,132.25 272.86 5,967,777.09 1,489,849.63 0.34 1,732.62 MWD+IFR-AK-CAZ-SC(6) 4,049.53 63.36 12.41 2,927.84 2,856.91 2,214.31 289.93 5,967,858.79 1,489,868.35 1.25 1,796.12 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 11:49:23AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,143.15 63.31 13.77 2,969.85 2,898.92 2,295.80 308.88 5,967,939.87 1,489,888.93 1.30 1,858.20 MWD+IFR-AK-CAZ-SC(6) 4,236.34 62.87 14.41 3,012.03 2,941.10 2,376.39 329.11 5,968,020.04 1,489,910.77 0.77 1,918.88 MWD+IFR-AK-CAZ-SC(6) 4,330.40 63.05 13.48 3,054.79 2,983.86 2,457.70 349.30 5,968,100.92 1,489,932.59 0.90 1,980.21 MWD+IFR-AK-CAZ-SC(6) 4,425.49 62.81 11.86 3,098.07 3,027.14 2,540.31 367.87 5,968,183.14 1,489,952.82 1.54 2,043.46 MWD+IFR-AK-CAZ-SC(6) 4,519.13 62.92 10.68 3,140.77 3,069.84 2,622.03 384.16 5,968,264.51 1,489,970.74 1.13 2,107.04 MWD+IFR-AK-CAZ-SC(6) 4,613.19 63.14 10.08 3,183.43 3,112.50 2,704.49 399.26 5,968,346.64 1,489,987.50 0.61 2,171.84 MWD+IFR-AK-CAZ-SC(6) 4,706.78 63.07 9.44 3,225.77 3,154.84 2,786.75 413.41 5,968,428.59 1,490,003.29 0.61 2,236.92 MWD+IFR-AK-CAZ-SC(6) 4,801.41 63.04 10.64 3,268.65 3,197.72 2,869.81 428.12 5,968,511.34 1,490,019.66 1.13 2,302.44 MWD+IFR-AK-CAZ-SC(6) 4,895.24 63.11 12.17 3,311.14 3,240.21 2,951.82 444.66 5,968,592.99 1,490,037.85 1.46 2,366.14 MWD+IFR-AK-CAZ-SC(6) 4,990.46 62.94 13.50 3,354.34 3,283.41 3,034.55 463.51 5,968,675.32 1,490,058.36 1.26 2,429.37 MWD+IFR-AK-CAZ-SC(6) 5,084.21 63.08 12.56 3,396.88 3,325.95 3,115.94 482.34 5,968,756.31 1,490,078.82 0.91 2,491.42 MWD+IFR-AK-CAZ-SC(6) 5,177.74 62.91 14.45 3,439.36 3,368.43 3,196.96 501.80 5,968,836.92 1,490,099.90 1.81 2,552.85 MWD+IFR-AK-CAZ-SC(6) 5,271.95 63.01 14.28 3,482.18 3,411.25 3,278.25 522.62 5,968,917.77 1,490,122.35 0.19 2,613.85 MWD+IFR-AK-CAZ-SC(6) 5,365.66 63.01 12.62 3,524.72 3,453.79 3,359.46 542.04 5,968,998.56 1,490,143.40 1.58 2,675.46 MWD+IFR-AK-CAZ-SC(6) 5,459.19 62.97 10.81 3,567.19 3,496.26 3,441.05 558.96 5,969,079.79 1,490,161.95 1.72 2,738.62 MWD+IFR-AK-CAZ-SC(6) 5,553.61 63.32 11.12 3,609.85 3,538.92 3,523.75 574.98 5,969,162.14 1,490,179.63 0.47 2,803.18 MWD+IFR-AK-CAZ-SC(6) 5,647.87 62.93 9.93 3,652.46 3,581.53 3,606.41 590.34 5,969,244.47 1,490,196.65 1.20 2,868.03 MWD+IFR-AK-CAZ-SC(6) 5,741.96 63.21 8.40 3,695.07 3,624.14 3,689.22 603.70 5,969,326.99 1,490,211.67 1.48 2,933.99 MWD+IFR-AK-CAZ-SC(6) 5,836.40 63.11 10.71 3,737.72 3,666.79 3,772.31 617.69 5,969,409.78 1,490,227.32 2.19 2,999.88 MWD+IFR-AK-CAZ-SC(6) 5,930.92 63.05 12.55 3,780.51 3,709.58 3,854.86 634.68 5,969,491.96 1,490,245.96 1.74 3,063.84 MWD+IFR-AK-CAZ-SC(6) 6,025.42 63.21 12.06 3,823.23 3,752.30 3,937.22 652.64 5,969,573.93 1,490,265.58 0.49 3,127.16 MWD+IFR-AK-CAZ-SC(6) 6,118.98 63.17 12.69 3,865.42 3,794.49 4,018.78 670.54 5,969,655.11 1,490,285.10 0.60 3,189.82 MWD+IFR-AK-CAZ-SC(6) 6,212.97 63.14 14.23 3,907.87 3,836.94 4,100.33 690.05 5,969,736.25 1,490,306.26 1.46 3,251.69 MWD+IFR-AK-CAZ-SC(6) 6,307.33 63.07 13.39 3,950.56 3,879.63 4,182.05 710.14 5,969,817.55 1,490,327.98 0.80 3,313.42 MWD+IFR-AK-CAZ-SC(6) 6,401.88 63.05 12.47 3,993.39 3,922.46 4,264.20 729.00 5,969,899.30 1,490,348.49 0.87 3,376.13 MWD+IFR-AK-CAZ-SC(6) 6,495.08 63.07 11.69 4,035.62 3,964.69 4,345.45 746.39 5,969,980.17 1,490,367.50 0.75 3,438.76 MWD+IFR-AK-CAZ-SC(6) 6,589.70 63.31 10.63 4,078.30 4,007.37 4,428.30 762.73 5,970,062.67 1,490,385.51 1.03 3,503.30 MWD+IFR-AK-CAZ-SC(6) 6,683.25 63.10 10.57 4,120.47 4,049.54 4,510.38 778.10 5,970,144.42 1,490,402.51 0.23 3,567.64 MWD+IFR-AK-CAZ-SC(6) 6,778.11 63.28 10.89 4,163.25 4,092.32 4,593.56 793.86 5,970,227.26 1,490,419.94 0.36 3,632.75 MWD+IFR-AK-CAZ-SC(6) 6,872.00 63.08 12.00 4,205.62 4,134.69 4,675.68 810.48 5,970,309.03 1,490,438.21 1.08 3,696.52 MWD+IFR-AK-CAZ-SC(6) 6,966.53 63.28 11.56 4,248.27 4,177.34 4,758.27 827.71 5,970,391.24 1,490,457.09 0.47 3,760.40 MWD+IFR-AK-CAZ-SC(6) 7,061.06 63.17 10.95 4,290.85 4,219.92 4,841.04 844.18 5,970,473.66 1,490,475.22 0.59 3,824.80 MWD+IFR-AK-CAZ-SC(6) 7,152.64 63.11 10.27 4,332.23 4,261.30 4,921.34 859.22 5,970,553.64 1,490,491.87 0.67 3,887.74 MWD+IFR-AK-CAZ-SC(6) 7,245.91 63.11 11.41 4,374.41 4,303.48 5,003.04 874.86 5,970,635.00 1,490,509.15 1.09 3,951.62 MWD+IFR-AK-CAZ-SC(6) 7,340.45 63.04 10.97 4,417.23 4,346.30 5,085.73 891.22 5,970,717.34 1,490,527.17 0.42 4,016.01 MWD+IFR-AK-CAZ-SC(6) 7,434.38 63.15 11.56 4,459.73 4,388.80 5,167.88 907.59 5,970,799.13 1,490,545.18 0.57 4,079.92 MWD+IFR-AK-CAZ-SC(6) 7,528.64 63.02 12.13 4,502.40 4,431.47 5,250.14 924.84 5,970,881.02 1,490,564.08 0.56 4,143.50 MWD+IFR-AK-CAZ-SC(6) 7,623.79 63.05 13.32 4,545.55 4,474.62 5,332.86 943.52 5,970,963.35 1,490,584.42 1.12 4,206.80 MWD+IFR-AK-CAZ-SC(6) 7,718.35 63.11 14.15 4,588.36 4,517.43 5,414.76 963.54 5,971,044.82 1,490,606.08 0.79 4,268.72 MWD+IFR-AK-CAZ-SC(6) 7,812.20 63.06 14.00 4,630.84 4,559.91 5,495.93 983.89 5,971,125.56 1,490,628.05 0.15 4,329.85 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 11:49:23AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 7,906.58 63.01 12.84 4,673.64 4,602.71 5,577.75 1,003.41 5,971,206.97 1,490,649.21 1.10 4,391.95 MWD+IFR-AK-CAZ-SC(6) 8,001.11 62.99 11.73 4,716.55 4,645.62 5,660.05 1,021.33 5,971,288.88 1,490,668.78 1.05 4,455.24 MWD+IFR-AK-CAZ-SC(6) 8,095.79 62.95 11.47 4,759.58 4,688.65 5,742.66 1,038.29 5,971,371.13 1,490,687.40 0.25 4,519.27 MWD+IFR-AK-CAZ-SC(6) 8,189.03 63.15 10.62 4,801.84 4,730.91 5,824.24 1,054.21 5,971,452.37 1,490,704.95 0.84 4,582.90 MWD+IFR-AK-CAZ-SC(6) 8,284.14 63.21 11.40 4,844.75 4,773.82 5,907.55 1,070.42 5,971,535.33 1,490,722.83 0.73 4,647.91 MWD+IFR-AK-CAZ-SC(6) 8,378.30 63.17 11.91 4,887.22 4,816.29 5,989.86 1,087.40 5,971,617.27 1,490,741.46 0.49 4,711.67 MWD+IFR-AK-CAZ-SC(6) 8,473.66 63.01 12.94 4,930.38 4,859.45 6,072.90 1,105.69 5,971,699.92 1,490,761.42 0.98 4,775.43 MWD+IFR-AK-CAZ-SC(6) 8,568.33 63.18 12.37 4,973.22 4,902.29 6,155.27 1,124.19 5,971,781.90 1,490,781.56 0.57 4,838.50 MWD+IFR-AK-CAZ-SC(6) 8,662.37 62.94 14.00 5,015.83 4,944.90 6,236.89 1,143.31 5,971,863.12 1,490,802.32 1.57 4,900.62 MWD+IFR-AK-CAZ-SC(6) 8,757.47 63.02 13.62 5,059.03 4,988.10 6,319.16 1,163.53 5,971,944.96 1,490,824.19 0.37 4,962.77 MWD+IFR-AK-CAZ-SC(6) 8,850.32 62.81 13.05 5,101.31 5,030.38 6,399.60 1,182.60 5,972,024.99 1,490,844.87 0.59 5,023.88 MWD+IFR-AK-CAZ-SC(6) 8,942.87 63.22 13.04 5,143.31 5,072.38 6,479.95 1,201.21 5,972,104.94 1,490,865.09 0.44 5,085.13 MWD+IFR-AK-CAZ-SC(6) 9,037.33 62.98 13.61 5,186.04 5,115.11 6,561.92 1,220.63 5,972,186.50 1,490,886.15 0.60 5,147.41 MWD+IFR-AK-CAZ-SC(6) 9,130.73 63.03 13.66 5,228.44 5,157.51 6,642.79 1,240.25 5,972,266.96 1,490,907.39 0.07 5,208.63 MWD+IFR-AK-CAZ-SC(6) 9,224.56 62.82 13.68 5,271.15 5,200.22 6,723.97 1,259.99 5,972,347.72 1,490,928.76 0.22 5,270.06 MWD+IFR-AK-CAZ-SC(6) 9,318.28 62.79 14.34 5,313.98 5,243.05 6,804.85 1,280.17 5,972,428.17 1,490,950.56 0.63 5,331.02 MWD+IFR-AK-CAZ-SC(6) 9,413.52 63.00 13.23 5,357.37 5,286.44 6,887.19 1,300.37 5,972,510.08 1,490,972.41 1.06 5,393.24 MWD+IFR-AK-CAZ-SC(6) 9,505.61 62.93 12.09 5,399.23 5,328.30 6,967.22 1,318.35 5,972,589.73 1,490,991.99 1.11 5,454.52 MWD+IFR-AK-CAZ-SC(6) 9,599.57 63.61 10.72 5,441.50 5,370.57 7,049.48 1,334.94 5,972,671.63 1,491,010.23 1.49 5,518.42 MWD+IFR-AK-CAZ-SC(6) 9,694.49 63.42 11.25 5,483.83 5,412.90 7,132.88 1,351.13 5,972,754.68 1,491,028.09 0.54 5,583.52 MWD+IFR-AK-CAZ-SC(6) 9,788.74 63.36 10.30 5,526.04 5,455.11 7,215.66 1,366.88 5,972,837.12 1,491,045.50 0.90 5,648.28 MWD+IFR-AK-CAZ-SC(6) 9,883.29 63.45 10.34 5,568.37 5,497.44 7,298.84 1,382.03 5,972,919.97 1,491,062.31 0.10 5,713.69 MWD+IFR-AK-CAZ-SC(6) 9,977.52 62.93 10.48 5,610.87 5,539.94 7,381.56 1,397.23 5,973,002.36 1,491,079.17 0.57 5,778.67 MWD+IFR-AK-CAZ-SC(6) 10,071.11 63.47 11.53 5,653.07 5,582.14 7,463.56 1,413.17 5,973,084.02 1,491,096.76 1.16 5,842.65 MWD+IFR-AK-CAZ-SC(6) 10,165.79 62.54 12.25 5,696.05 5,625.12 7,546.11 1,430.55 5,973,166.20 1,491,115.79 1.19 5,906.43 MWD+IFR-AK-CAZ-SC(6) 10,260.40 62.93 12.52 5,739.39 5,668.46 7,628.25 1,448.59 5,973,247.96 1,491,135.47 0.48 5,969.53 MWD+IFR-AK-CAZ-SC(6) 10,355.00 63.02 13.29 5,782.37 5,711.44 7,710.39 1,467.41 5,973,329.70 1,491,155.94 0.73 6,032.24 MWD+IFR-AK-CAZ-SC(6) 10,448.49 62.67 12.54 5,825.04 5,754.11 7,791.47 1,486.00 5,973,410.38 1,491,176.16 0.81 6,094.14 MWD+IFR-AK-CAZ-SC(6) 10,542.00 63.23 11.91 5,867.57 5,796.64 7,872.86 1,503.64 5,973,491.39 1,491,195.42 0.85 6,156.78 MWD+IFR-AK-CAZ-SC(6) 10,635.69 63.12 11.90 5,909.85 5,838.92 7,954.67 1,520.89 5,973,572.83 1,491,214.31 0.12 6,219.97 MWD+IFR-AK-CAZ-SC(6) 10,729.09 63.01 11.68 5,952.16 5,881.23 8,036.18 1,537.90 5,973,653.98 1,491,232.96 0.24 6,283.02 MWD+IFR-AK-CAZ-SC(6) 10,822.63 63.33 11.26 5,994.37 5,923.44 8,117.99 1,554.50 5,973,735.43 1,491,251.19 0.53 6,346.52 MWD+IFR-AK-CAZ-SC(6) 10,916.45 63.00 11.60 6,036.73 5,965.80 8,200.04 1,571.09 5,973,817.13 1,491,269.43 0.48 6,410.24 MWD+IFR-AK-CAZ-SC(6) 11,009.82 63.07 11.26 6,079.07 6,008.14 8,281.61 1,587.58 5,973,898.34 1,491,287.55 0.33 6,473.59 MWD+IFR-AK-CAZ-SC(6) 11,104.11 63.28 11.03 6,121.62 6,050.69 8,364.17 1,603.84 5,973,980.55 1,491,305.47 0.31 6,537.91 MWD+IFR-AK-CAZ-SC(6) 11,196.28 63.31 11.83 6,163.04 6,092.11 8,444.87 1,620.16 5,974,060.90 1,491,323.41 0.78 6,600.58 MWD+IFR-AK-CAZ-SC(6) 11,291.67 62.94 12.01 6,206.16 6,135.23 8,528.12 1,637.73 5,974,143.78 1,491,342.65 0.42 6,664.88 MWD+IFR-AK-CAZ-SC(6) 11,390.45 63.30 12.57 6,250.82 6,179.89 8,614.21 1,656.49 5,974,229.47 1,491,363.13 0.62 6,731.08 MWD+IFR-AK-CAZ-SC(6) 11,478.46 62.91 12.77 6,290.63 6,219.70 8,690.79 1,673.70 5,974,305.68 1,491,381.88 0.49 6,789.71 MWD+IFR-AK-CAZ-SC(6) 11,572.12 63.15 13.21 6,333.11 6,262.18 8,772.13 1,692.47 5,974,386.62 1,491,402.27 0.49 6,851.75 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 11:49:23AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,666.71 63.12 13.25 6,375.85 6,304.92 8,854.27 1,711.78 5,974,468.35 1,491,423.23 0.05 6,914.23 MWD+IFR-AK-CAZ-SC(6) 11,760.40 63.04 12.17 6,418.27 6,347.34 8,935.76 1,730.16 5,974,549.45 1,491,443.24 1.03 6,976.59 MWD+IFR-AK-CAZ-SC(6) 11,854.28 63.09 11.07 6,460.80 6,389.87 9,017.74 1,747.02 5,974,631.06 1,491,461.74 1.05 7,040.12 MWD+IFR-AK-CAZ-SC(6) 11,949.26 62.98 11.98 6,503.87 6,432.94 9,100.68 1,763.93 5,974,713.65 1,491,480.31 0.86 7,104.47 MWD+IFR-AK-CAZ-SC(6) 12,041.95 63.26 12.06 6,545.77 6,474.84 9,181.55 1,781.15 5,974,794.14 1,491,499.15 0.31 7,166.84 MWD+IFR-AK-CAZ-SC(6) 12,135.18 63.25 12.35 6,587.73 6,516.80 9,262.92 1,798.75 5,974,875.14 1,491,518.38 0.28 7,229.48 MWD+IFR-AK-CAZ-SC(6) 12,228.87 62.94 13.17 6,630.13 6,559.20 9,344.40 1,817.20 5,974,956.23 1,491,538.47 0.85 7,291.80 MWD+IFR-AK-CAZ-SC(6) 12,322.52 63.31 12.62 6,672.46 6,601.53 9,425.83 1,835.84 5,975,037.26 1,491,558.74 0.66 7,353.99 MWD+IFR-AK-CAZ-SC(6) 12,417.38 63.05 11.60 6,715.26 6,644.33 9,508.60 1,853.60 5,975,119.65 1,491,578.16 1.00 7,417.77 MWD+IFR-AK-CAZ-SC(6) 12,510.87 63.02 11.00 6,757.65 6,686.72 9,590.31 1,869.93 5,975,201.01 1,491,596.12 0.57 7,481.32 MWD+IFR-AK-CAZ-SC(6) 12,603.06 63.12 11.24 6,799.41 6,728.48 9,670.96 1,885.78 5,975,281.32 1,491,613.59 0.26 7,544.17 MWD+IFR-AK-CAZ-SC(6) 12,697.18 62.84 10.81 6,842.17 6,771.24 9,753.26 1,901.82 5,975,363.27 1,491,631.28 0.50 7,608.38 MWD+IFR-AK-CAZ-SC(6) 12,790.91 63.09 10.44 6,884.77 6,813.84 9,835.32 1,917.21 5,975,445.00 1,491,648.31 0.44 7,672.68 MWD+IFR-AK-CAZ-SC(6) 12,884.80 63.17 10.47 6,927.20 6,856.27 9,917.68 1,932.41 5,975,527.03 1,491,665.16 0.09 7,737.35 MWD+IFR-AK-CAZ-SC(6) 12,978.94 63.08 10.31 6,969.76 6,898.83 10,000.28 1,947.55 5,975,609.30 1,491,681.96 0.18 7,802.25 MWD+IFR-AK-CAZ-SC(6) 13,072.28 63.13 10.29 7,011.98 6,941.05 10,082.18 1,962.44 5,975,690.88 1,491,698.49 0.06 7,866.66 MWD+IFR-AK-CAZ-SC(6) 13,166.26 63.71 9.53 7,054.03 6,983.10 10,164.97 1,976.90 5,975,773.36 1,491,714.61 0.95 7,932.06 MWD+IFR-AK-CAZ-SC(6) 13,259.54 65.07 6.32 7,094.36 7,023.43 10,248.27 1,988.48 5,975,856.40 1,491,727.86 3.43 7,999.30 MWD+IFR-AK-CAZ-SC(6) 13,353.66 65.36 3.42 7,133.82 7,062.89 10,333.40 1,995.73 5,975,941.36 1,491,736.82 2.81 8,070.24 MWD+IFR-AK-CAZ-SC(6) 13,447.09 65.82 1.29 7,172.44 7,101.51 10,418.40 1,999.22 5,976,026.27 1,491,742.02 2.13 8,142.89 MWD+IFR-AK-CAZ-SC(6) 13,540.30 67.13 359.30 7,209.65 7,138.72 10,503.85 1,999.66 5,976,111.69 1,491,744.17 2.41 8,217.42 MWD+IFR-AK-CAZ-SC(6) 13,634.11 69.29 356.39 7,244.47 7,173.54 10,590.88 1,996.37 5,976,198.76 1,491,742.63 3.69 8,295.14 MWD+IFR-AK-CAZ-SC(6) 13,727.73 71.67 354.23 7,275.76 7,204.83 10,678.81 1,989.14 5,976,286.81 1,491,737.17 3.35 8,375.54 MWD+IFR-AK-CAZ-SC(6) 13,821.63 73.64 352.97 7,303.75 7,232.82 10,767.87 1,979.14 5,976,376.05 1,491,728.97 2.46 8,458.29 MWD+IFR-AK-CAZ-SC(6) 13,915.09 74.45 351.64 7,329.44 7,258.51 10,856.92 1,967.11 5,976,465.32 1,491,718.73 1.62 8,542.00 MWD+IFR-AK-CAZ-SC(6) 14,008.99 77.21 349.76 7,352.43 7,281.50 10,946.75 1,952.39 5,976,555.42 1,491,705.82 3.52 8,627.71 MWD+IFR-AK-CAZ-SC(6) 14,102.96 79.55 346.72 7,371.36 7,300.43 11,036.85 1,933.62 5,976,645.86 1,491,688.87 4.03 8,715.60 MWD+IFR-AK-CAZ-SC(6) 14,196.39 82.58 343.00 7,385.87 7,314.94 11,125.91 1,909.51 5,976,735.39 1,491,666.55 5.10 8,805.19 MWD+IFR-AK-CAZ-SC(6) 14,290.68 85.43 340.62 7,395.72 7,324.79 11,214.98 1,880.24 5,976,825.02 1,491,639.08 3.93 8,897.28 MWD+IFR-AK-CAZ-SC(6) 14,340.65 86.94 338.69 7,399.04 7,328.11 11,261.72 1,862.90 5,976,872.10 1,491,622.69 4.91 8,946.57 NOT an Actual Survey (6) 7-518"x 9-718"by 11" 14,385.36 88.30 336.96 7,400.90 7,329.97 11,303.09 1,846.04 5,976,913.79 1,491,606.66 4.91 8,990.92 MWD+IFR-AK-CAZ-SC(6) 14,418.67 89.04 335.19 7,401.67 7,330.74 11,333.53 1,832.54 5,976,944.49 1,491,593.77 5.76 9,024.09 MWD+IFR-AK-CAZ-SC(6) 14,514.76 91.30 330.78 7,401.39 7,330.46 11,419.10 1,788.91 5,977,030.93 1,491,551.87 5.16 9,120.09 MWD+IFR-AK-CAZ-SC(6) 14,608.02 90.79 329.62 7,399.69 7,328.76 11,500.02 1,742.57 5,977,112.75 1,491,507.17 1.36 9,213.33 MWD+IFR-AK-CAZ-SC(6) 14,704.29 91.55 327.85 7,397.72 7,326.79 11,582.29 1,692.62 5,977,196.00 1,491,458.89 2.00 9,309.50 MWD+IFR-AK-CAZ-SC(6) 14,798.61 91.64 326.93 7,395.10 7,324.17 11,661.71 1,641.81 5,977,276.42 1,491,409.69 0.98 9,403.59 MWD+IFR-AK-CAZ-SC(6) 14,893.77 91.57 326.08 7,392.43 7,321.50 11,741.03 1,589.31 5,977,356.77 1,491,358.80 0.90 9,498.42 MWD+IFR-AK-CAZ-SC(6) 14,988.78 91.63 326.49 7,389.78 7,318.85 11,820.03 1,536.60 5,977,436.81 1,491,307.69 0.44 9,593.07 MWD+IFR-AK-CAZ-SC(6) 15,084.07 90.06 325.97 7,388.37 7,317.44 11,899.23 1,483.64 5,977,517.05 1,491,256.33 1.74 9,688.02 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 11:49:23AM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,180.90 90.24 325.84 7,388.12 7,317.19 11,979.42 1,429.36 5,977,598.31 1,491,203.68 0.23 9,784.47 MWD+1FR-AK-CAZ-SC(6) 15,275.81 90.42 326.79 7,387.57 7,316.64 12,058.39 1,376.72 5,977,678.32 1,491,152.64 1.02 9,879.06 MWD+IFR-AK-CAZ-SC(6) 15,370.39 89.62 327.37 7,387.54 7,316.61 12,137.78 1,325.32 5,977,758.72 1,491,102.85 1.04 9,973.42 MWD+IFR-AK-CAZ-SC(6) 15,465.39 89.31 330.83 7,388.43 7,317.50 12,219.28 1,276.54 5,977,841.18 1,491,055.73 3.66 10,068.34 MWD+1FR-AK-CAZ-SC(6) 15,561.80 89.35 334.66 7,389.55 7,318.62 12,304.97 1,232.40 5,977,927.72 1,491,013.32 3.97 10,164.69 MWD+1FR-AK-CAZ-SC(6) 15,656.70 89.69 336.14 7,390.35 7,319.42 12,391.25 1,192.90 5,978,014.78 1,490,975.56 1.60 10,259.30 MWD+IFR-AK-CAZ-SC(6) 15,752.09 89.65 335.78 7,390.90 7,319.97 12,478.36 1,154.04 5,978,102.65 1,490,938.46 0.38 10,354.33 MWD+1FR-AK-CAZ-SC(6) 15,848.54 89.76 334.42 7,391.40 7,320.47 12,565.84 1,113.43 5,978,190.92 1,490,899.63 1.41 10,450.53 MWD+IFR-AK-CAZ-SC(6) 15,944.42 89.77 334.75 7,391.79 7,320.86 12,652.44 1,072.28 5,978,278.32 1,490,860.23 0.34 10,546.22 MWD+IFR-AK-CAZ-SC(6) 16,039.41 88.83 335.18 7,392.95 7,322.02 12,738.50 1,032.09 5,978,365.16 1,490,821.78 1.09 10,640.98 MWD+IFR-AK-CAZ-SC(6) 16,135.23 88.80 335.25 7,394.93 7,324.00 12,825.48 991.93 5,978,452.92 1,490,783.37 0.08 10,736.52 MWD+IFR-AK-CAZ-SC(6) 16,230.34 89.84 333.71 7,396.06 7,325.13 12,911.30 950.96 5,978,539.54 1,490,744.14 1.95 10,831.44 MWD+IFR-AK-CAZ-SC(6) 16,325.78 89.93 333.41 7,396.25 7,325.32 12,996.75 908.46 5,978,625.83 1,490,703.37 0.33 10,926.78 MWD+IFR-AK-CAZ-SC(6) 16,419.08 90.79 332.71 7,395.66 7,324.73 13,079.92 866.19 5,978,709.83 1,490,662.79 1.19 11,020.02 MWD+IFR-AK-CAZ-SC(6) 16,514.32 91.23 332.81 7,393.99 7,323.06 13,164.59 822.61 5,978,795.35 1,490,620.91 0.47 11,115.20 MWD+IFR-AK-CAZ-SC(6) 16,609.87 91.20 332.59 7,391.96 7,321.03 13,249.48 778.79 5,978,881.09 1,490,578.82 0.23 11,210.69 MWD+IFR-AK-CAZ-SC(6) 16,705.02 91.23 331.55 7,389.94 7,319.01 13,333.52 734.24 5,978,966.01 1,490,535.96 1.09 11,305.80 MWD+IFR-AK-CAZ-SC(6) 16,801.11 91.34 331.58 7,387.79 7,316.86 13,418.00 688.49 5,979,051.38 1,490,491.93 0.12 11,401.86 MWD+IFR-AK-CAZ-SC(6) 16,896.86 90.85 330.99 7,385.96 7,315.03 13,501.96 642.50 5,979,136.24 1,490,447.63 0.80 11,497.59 MWD+IFR-AK-CAZ-SC(6) 16,991.58 90.00 331.09 7,385.25 7,314.32 13,584.83 596.64 5,979,220.01 1,490,403.45 0.90 11,592.31 MWD+IFR-AK-CAZ-SC(6) 17,087.48 89.89 330.24 7,385.35 7,314.42 13,668.43 549.66 5,979,304.54 1,490,358.16 0.89 11,688.20 MWD+IFR-AK-CAZ-SC(6) 17,184.52 90.17 330.30 7,385.30 7,314.37 13,752.70 501.53 5,979,389.75 1,490,311.74 0.30 11,785.24 MWD+IFR-AK-CAZ-SC(6) 17,278.91 90.80 331.06 7,384.50 7,313.57 13,835.00 455.31 5,979,472.95 1,490,267.19 1.05 11,879.62 MWD+IFR-AK-CAZ-SC(6) 17,373.47 90.85 331.69 7,383.14 7,312.21 13,917.99 410.02 5,979,556.83 1,490,223.57 0.67 11,974.17 MWD+IFR-AK-CAZ-SC(6) 17,469.08 90.34 331.37 7,382.14 7,311.21 14,002.03 364.44 5,979,641.76 1,490,179.70 0.63 12,069.77 MWD+IFR-AK-CAZ-SC(6) 17,563.66 90.41 332.64 7,381.52 7,310.59 14,085.54 320.05 5,979,726.14 1,490,137.00 1.34 12,164.33 MWD+IFR-AK-CAZ-SC(6) 17,659.45 90.44 333.60 7,380.81 7,309.88 14,170.98 276.74 5,979,812.42 1,490,095.42 1.00 12,260.05 MWD+IFR-AK-CAZ-SC(6) 17,753.82 90.34 334.97 7,380.17 7,309.24 14,256.00 235.80 5,979,898.24 1,490,056.19 1.46 12,354.26 MWD+IFR-AK-CAZ-SC(6) 17,849.43 90.37 335.22 7,379.58 7,308.65 14,342.72 195.53 5,979,985.75 1,490,017.69 0.26 12,449.62 MWD+IFR-AK-CAZ-SC(6) 17,944.77 90.34 335.47 7,378.99 7,308.06 14,429.36 155.76 5,980,073.17 1,489,979.67 0.26 12,544.69 MWD+IFR-AK-CAZ-SC(6) 18,040.83 90.27 335.89 7,378.48 7,307.55 14,516.90 116.20 5,980,161.47 1,489,941.88 0.44 12,640.43 MWD+IFR-AK-CAZ-SC(6) 18,134.93 90.00 336.02 7,378.25 7,307.32 14,602.83 77.86 5,980,248.15 1,489,905.27 0.32 12,734.17 MWD+IFR-AK-CAZ-SC(6) 18,230.43 89.41 335.35 7,378.75 7,307.82 14,689.86 38.54 5,980,335.95 1,489,867.71 0.93 12,829.35 MWD+IFR-AK-CAZ-SC(6) 18,325.63 88.87 334.66 7,380.18 7,309.25 14,776.13 -1.68 5,980,423.00 1,489,829.24 0.92 12,924.31 MWD+IFR-AK-CAZ-SC(6) 18,421.05 88.42 334.65 7,382.43 7,311.50 14,862.34 -42.51 5,980,510.01 1,489,790.14 0.47 13,019.51 MWD+IFR-AK-CAZ-SC(6) 18,515.56 87.84 333.91 7,385.52 7,314.59 14,947.44 -83.51 5,980,595.91 1,489,750.87 0.99 13,113.81 MWD+IFR-AK-CAZ-SC(6) 18,612.05 87.32 333.45 7,389.59 7,318.66 15,033.85 -126.25 5,980,683.16 1,489,709.88 0.72 13,210.11 MWD+IFR-AK-CAZ-SC(6) 18,708.10 86.70 333.00 7,394.60 7,323.67 15,119.49 -169.46 5,980,769.64 1,489,668.40 0.80 13,305.96 MWD+IFR-AK-CAZ-SC(6) 18,802.30 88.73 333.65 7,398.36 7,327.43 15,203.59 -211.71 5,980,854.57 1,489,627.85 2.26 13,400.00 MWD+IFR-AK-CAZ-SC(6) 18,891.28 92.08 332.15 7,397.73 7,326.80 15,282.78 -252.24 5,980,934.55 1,489,588.93 4.12 13,488.91 MWD+IFR-AK-CAZ-SC(6) 11/30/2015 11:49:23AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 18,988.75 94.04 331.45 7,392.52 7,321.59 15,368.56 -298.23 5,981,021.23 1,489,544.67 2.13 13,586.23 MWD+IFR-AK-CAZ-SC(6) 19,087.81 94.15 330.07 7,385.45 7,314.52 15,454.77 -346.49 5,981,108.39 1,489,498.15 1.39 13,685.03 MWD+IFR-AK-CAZ-SC(6) 19,183.81 94.22 328.41 7,378.44 7,307.51 15,537.04 -395.46 5,981,191.62 1,489,450.85 1.73 13,780.73 MWD+IFR-AK-CAZ-SC(6) 19,278.08 94.18 328.83 7,371.54 7,300.61 15,617.31 -444.41 5,981,272.85 1,489,403.53 0.45 13,874.66 MWD+IFR-AK-CAZ-SC(6) 19,372.36 94.15 328.37 7,364.69 7,293.76 15,697.57 -493.41 5,981,354.07 1,489,356.16 0.49 13,968.61 MWD+IFR-AK-CAZ-SC(6) 19,468.80 93.99 328.43 7,357.85 7,286.92 15,779.50 -543.81 5,981,436.99 1,489,307.42 0.18 14,064.71 MWD+IFR-AK-CAZ-SC(6) 19,563.70 93.15 327.57 7,351.94 7,281.01 15,859.82 -594.00 5,981,518.30 1,489,258.85 1.27 14,159.29 MWD+IFR-AK-CAZ-SC(6) 19,659.57 93.21 329.81 7,346.62 7,275.69 15,941.60 -643.74 5,981,601.06 1,489,210.77 2.33 14,254.93 MWD+IFR-AK-CAZ-SC(6) 19,753.65 92.02 329.85 7,342.33 7,271.40 16,022.85 -690.97 5,981,683.23 1,489,165.18 1.27 14,348.89 MWD+IFR-AK-CAZ-SC(6) 19,849.98 91.13 331.05 7,339.68 7,268.75 16,106.62 -738.46 5,981,767.93 1,489,119.39 1.55 14,445.18 MWD+IFR-AK-CAZ-SC(6) 19,945.55 90.13 329.96 7,338.63 7,267.70 16,189.79 -785.51 5,981,852.03 1,489,074.02 1.55 14,540.74 MWD+IFR-AK-CAZ-SC(6) 20,040.96 90.06 330.35 7,338.47 7,267.54 16,272.55 -832.99 5,981,935.72 1,489,028.22 0.42 14,636.14 MWD+IFR-AK-CAZ-SC(6) 20,135.12 90.13 331.41 7,338.31 7,267.38 16,354.81 -878.82 5,982,018.87 1,488,984.06 1.13 14,730.29 MWD+IFR-AK-CAZ-SC(6) 20,231.42 90.10 330.96 7,338.12 7,267.19 16,439.18 -925.23 5,982,104.16 1,488,939.36 0.47 14,826.59 MWD+IFR-AK-CAZ-SC(6) 20,326.61 90.13 332.00 7,337.93 7,267.00 16,522.82 -970.68 5,982,188.68 1,488,895.60 1.09 14,921.78 MWD+IFR-AK-CAZ-SC(6) 20,421.08 90.03 332.62 7,337.80 7,266.87 16,606.47 -1,014.58 5,982,273.19 1,488,853.40 0.66 15,016.22 MWD+IFR-AK-CAZ-SC(6) 20,516.76 90.59 333.38 7,337.28 7,266.35 16,691.72 -1,058.02 5,982,359.29 1,488,811.68 0.99 15,111.84 MWD+1FR-AK-CAZ-SC(6) 20,613.10 90.65 333.89 7,336.24 7,265.31 16,778.03 -1,100.80 5,982,446.44 1,488,770.65 0.53 15,208.07 MWD+IFR-AK-CAZ-SC(6) 20,707.11 90.58 332.93 7,335.23 7,264.30 16,862.09 -1,142.87 5,982,531.32 1,488,730.27 1.02 15,302.00 MWD+IFR-AK-CAZ-SC(6) 20,802.44 90.58 333.31 7,334.26 7,263.33 16,947.12 -1,185.97 5,982,617.19 1,488,688.90 0.40 15,397.25 MWD+IFR-AK-CAZ-SC(6) 20,898.28 90.65 334.48 7,333.23 7,262.30 17,033.18 -1,228.14 5,982,704.07 1,488,648.47 1.22 15,492.97 MWD+IFR-AK-CAZ-SC(6) 20,939.03 90.72 333.72 7,332.75 7,261.82 17,069.83 -1,245.94 5,982,741.07 1,488,631.41 1.87 15,533.65 MWD+IFR-AK-CAZ-SC(6) 20,990.00 90.72 333.72 7,332.11 7,261.18 17,115.53 -1,268.50 5,982,787.21 1,488,609.77 0.00 15,584.56 NOT an Actual Survey 4-1/2"x 6-1/2" 20,999.00 90.72 333.72 7,331.99 7,261.06 17,123.60 -1,272.49 5,982,795.36 1,488,605.95 0.00 15,593.55 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. U Yes ❑ No I have checked to the best of my ability that the following data is correct: L] Surface Coordinates p Declination & Convergence p GRS Survey Corrections p Survey Tool Codes Vincent Digitally Signed by+ncaet Cam oat en=vnoent oaara. o=sddumbng.r,ou.Schlumbelger. SLB DE: Osara "m`"°x;;ir:14334com 4.o ar Client Representative: welfeng oar Date: 24-Nov-2015 11/30/2015 11:49:23AM Page 8 COMPASS 5000.1 Build 74 • • 21 51 46 26 49 7 Scbluniberger Transmittal#: 25N0V15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 2.i2oiS .I.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-03 Date Dispatched: 25-Nov-15 Job#: 15AKA0027 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2'TVD x x Scope Resistivity 5"MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(cDconocophillips.com AlaskaPTSPrintCenterslb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: 215146 •• i 26497 FINAL NADConversion Western North Slope CD5 Alpine West Pad CD5-03 Definitive Survey Report 24 November, 2015 NAD 27 • 0 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-03 Well Position +N/-S 0.00 usft Northing: 5,965,904.95 usfi Latitude: 70°18'50.253 N +EI-W 0.00 usft Easting: 349,500.86 usfi Longitude: 151°13'11.180 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 34.10 usft Wellbore CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2015 11/6/2015 17.93 80.83 57,471 Design CD5-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.83 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 331.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:: 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:: 2,393.84 2,393.84 CD5-03 Svy3-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 2,446.61 3,012.81 CD5-03 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1: 3,107.13 3,107.13 CD5-03 Svy5-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 3,201.32 20,939.03 CD5-03 Svy6-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -34.10 0.00 0.00 5,965,904.95 349,500.86 0.00 0.00 UNDEFINED 115.00 0.78 341.30 115.00 44.07 0.50 -0.17 5,965,905.46 349,500.70 0.99 0.52 NOT an Actual Survey (1) 20"x42" 706.73 6.66 341.30 705.22 634.29 36.84 -12.47 5,965,942.03 349,489.13 0.99 38.26 MWD+IFR-AK-CAZ-SC(1) 763.64 9.05 346.48 761.60 690.67 44.32 -14.57 5,965,949.55 349,487.18 4.38 45.83 MWD+IFR-AK-CAZ-SC(1) 857.86 10.91 350.45 854.39 783.46 60.32 -17.79 5,965,965.61 349,484.28 2.10 61.38 MWD+IFR-AK-CAZ-SC(1) 952.85 13.26 350.82 947.26 876.33 79.94 -21.02 5,965,985.29 349,481.45 2.48 80.10 MWD+IFR-AK-CAZ-SC(1) 1,046.87 16.13 351.66 1,038.20 967.27 103.51 -24.63 5,966,008.93 349,478.31 3.06 102.47 MWD+IFR-AK-CAZ-SC(1) 1,139.96 18.17 352.74 1,127.15 1,056.22 130.70 -28.34 5,966,036.19 349,475.14 2.22 128.06 MWD+IFR-AK-CAZ-SC(1) 1,234.44 19.22 353.12 1,216.64 1,145.71 160.76 -32.07 5,966,066.31 349,472.02 1.12 156.15 MWD+IFR-AK-CAZ-SC(1) 11/24/2015 2:17:48PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,329.46 21.62 352.72 1,305.68 1,234.75 193.65 -36.16 5,966,099.28 349,468.59 2.53 186.90 MWD+IFR-AK-CAZ-SC(1) 1,423.98 22.55 352.28 1,393.27 1,322.34 228.89 -40.80 5,966,134.59 349,464.66 1.00 219.97 MWD+IFR-AK-CAZ-SC(1) 1,518.01 23.21 353.74 1,479.90 1,408.97 265.17 -45.24 5,966,170.96 349,460.94 0.93 253.86 MWD+IFR-AK-CAZ-SC(1) 1,612.52 26.26 355.12 1,565.73 1,494.80 304.53 -49.05 5,966,210.38 349,457.92 3.28 290.12 MWD+IFR-AK-CAZ-SC(1) 1,705.02 29.72 357.69 1,647.40 1,576.47 347.84 -51.72 5,966,253.73 349,456.12 3.96 329.30 MWD+IFR-AK-CAZ-SC(1) 1,799.69 33.51 1.37 1,728.01 1,657.08 397.44 -52.04 5,966,303.32 349,456.80 4.49 372.83 MWD+IFR-AK-CAZ-SC(1) 1,893.56 36.33 2.16 1,804.97 1,734.04 451.14 -50.37 5,966,356.98 349,459.54 3.04 418.99 MWD+IFR-AK-CAZ-SC(1) 1,987.71 39.54 2.93 1,879.22 1,808.29 508.95 -47.79 5,966,414.72 349,463.28 3.45 468.31 MWD+IFR-AK-CAZ-SC(1) 2,082.01 42.89 4.47 1,950.15 1,879.22 570.94 -43.75 5,966,476.61 349,468.56 3.71 520.57 MWD+IFR-AK-CAZ-SC(1) 2,175.54 46.13 7.05 2,016.84 1,945.91 636.15 -37.13 5,966,541.67 349,476.49 3.97 574.39 MWD+IFR-AK-CAZ-SC(1) 2,270.65 49.64 7.72 2,080.62 2,009.69 706.11 -28.05 5,966,611.43 349,486.96 3.73 631.18 MWD+IFR-AK-CAZ-SC(1) 2,332.23 52.58 9.87 2,119.28 2,048.35 753.46 -20.71 5,966,658.62 349,495.26 5.49 669.03 MWD+IFR-AK-CAZ-SC(1) 2,393.40 53.25 9.01 2,156.17 2,085.24 801.60 -12.71 5,966,706.58 349,504.22 1.57 707.25 NOT an Actual Survey 10-3/4"x 13-1/2" 2,393.84 53.25 9.00 2,156.43 2,085.50 801.94 -12.65 5,966,706.93 349,504.28 1.57 707.53 INC+TREND(2) 2,446.61 54.40 8.42 2,187.58 2,116.65 844.05 -6.20 5,966,748.89 349,511.57 2.35 741.23 MWD+IFR-AK-CAZ-SC(3) 2,540.41 58.16 9.29 2,239.64 2,168.71 921.12 5.82 5,966,825.70 349,525.13 4.08 802.81 MWD+IFR-AK-CAZ-SC(3) 2,635.46 61.10 10.07 2,287.69 2,216.76 1,001.95 19.61 5,966,906.23 349,540.55 3.17 866.82 MWD+IFR-AK-CAZ-SC(3) 2,729.01 62.78 12.72 2,331.70 2,260.77 1,082.86 35.94 5,966,986.79 349,558.49 3.08 929.67 MWD+IFR-AK-CAZ-SC(3) 2,823.37 63.11 13.13 2,374.62 2,303.69 1,164.76 54.73 5,967,068.30 349,578.92 0.52 992.19 MWD+IFR-AK-CAZ-SC(3) 2,918.15 62.77 12.29 2,417.74 2,346.81 1,247.10 73.30 5,967,150.24 349,599.14 0.87 1,055.20 MWD+IFR-AK-CAZ-SC(3) 3,012.81 63.22 11.64 2,460.72 2,389.79 1,329.61 90.79 5,967,232.37 349,618.27 0.77 1,118.88 MWD+IFR-AK-CAZ-SC(3) 3,107.13 63.22 11.06 2,503.22 2,432.29 1,412.16 107.36 5,967,314.57 349,636.49 0.55 1,183.06 INC+TREND(4) 3,201.32 63.27 11.63 2,545.62 2,474.69 1,494.62 123.90 5,967,396.68 349,654.68 0.54 1,247.16 MWD+IFR-AK-CAZ-SC(5) 3,294.86 63.22 10.60 2,587.73 2,516.80 1,576.58 140.01 5,967,478.29 349,672.42 0.98 1,311.03 MWD+IFR-AK-CAZ-SC(5) 3,389.84 63.34 11.91 2,630.44 2,559.51 1,659.78 156.56 5,967,561.14 349,690.64 1.24 1,375.78 MWD+IFR-AK-CAZ-SC(5) 3,484.08 63.36 13.32 2,672.71 2,601.78 1,741.98 174.96 5,967,642.94 349,710.68 1.34 1,438.75 MWD+IFR-AK-CAZ-SC(5) 3,578.22 63.29 14.02 2,714.97 2,644.04 1,823.71 194.84 5,967,724.26 349,732.19 0.67 1,500.60 MWD+IFR-AK-CAZ-SC(5) 3,672.82 63.21 13.32 2,757.55 2,686.62 1,905.80 214.80 5,967,805.92 349,753.80 0.67 1,562.71 MWD+IFR-AK-CAZ-SC(5) 3,767.31 63.20 12.01 2,800.15 2,729.22 1,988.09 233.29 5,967,887.81 349,773.93 1.24 1,625.72 MWD+IFR-AK-CAZ-SC(5) 3,861.28 63.17 11.37 2,842.54 2,771.61 2,070.21 250.29 5,967,969.58 349,792.57 0.61 1,689.31 MWD+IFR-AK-CAZ-SC(5) 3,955.76 63.38 11.10 2,885.03 2,814.10 2,152.98 266.73 5,968,051.99 349,810.66 0.34 1,753.73 MWD+IFR-AK-CAZ-SC(5) 4,049.53 63.36 12.41 2,927.06 2,856.13 2,235.04 283.80 5,968,133.69 349,829.38 1.25 1,817.22 MWD+IFR-AK-CAZ-SC(5) 4,143.15 63.31 13.77 2,969.08 2,898.15 2,316.53 302.75 5,968,214.78 349,849.95 1.30 1,879.31 MWD+IFR-AK-CAZ-SC(5) 4,236.34 62.87 14.41 3,011.25 2,940.32 2,397.13 322.98 5,968,294.95 349,871.79 0.77 1,939.99 MWD+IFR-AK-CAZ-SC(5) 4,330.40 63.05 13.48 3,054.02 2,983.09 2,478.44 343.17 5,968,375.83 349,893.61 0.90 2,001.32 MWD+IFR-AK-CAZ-SC(5) 4,425.49 62.81 11.86 3,097.29 3,026.36 2,561.04 361.74 5,968,458.04 349,913.83 1.54 2,064.56 MWD+IFR-AK-CAZ-SC(5) 4,519.13 62.92 10.68 3,140.00 3,069.07 2,642.77 378.03 5,968,539.42 349,931.75 1.13 2,128.15 MWD+IFR-AK-CAZ-SC(5) 4,613.19 63.14 10.08 3,182.66 3,111.73 2,725.23 393.13 5,968,621.55 349,948.50 0.61 2,192.94 MWD+IFR-AK-CAZ-SC(5) 4,706.78 63.07 9.44 3,225.00 3,154.07 2,807.48 407.28 5,968,703.50 349,964.29 0.61 2,258.03 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 2:17:48PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,801.41 63.04 10.64 3,267.88 3,196.95 2,890.55 421.99 5,968,786.25 349,980.66 1.13 2,323.55 MW D+I FR-AK-CAZ-SC(5) 4,895.24 63.11 12.17 3,310.37 3,239.44 2,972.55 438.53 5,968,867.90 349,998.84 1.46 2,387.25 MWD+IFR-AK-CAZ-SC(5) 4,990.46 62.94 13.50 3,353.56 3,282.63 3,055.29 457.38 5,968,950.23 350,019.35 1.26 2,450.47 MWD+IFR-AK-CAZ-SC(5) 5,084.21 63.08 12.56 3,396.11 3,325.18 3,136.67 476.21 5,969,031.22 350,039.81 0.91 2,512.53 MWD+IFR-AK-CAZ-SC(5) 5,177.74 62.91 14.45 3,438.58 3,367.65 3,217.70 495.67 5,969,111.83 350,060.88 1.81 2,573.96 MWD+IFR-AK-CAZ-SC(5) 5,271.95 63.01 14.28 3,481.41 3,410.48 3,298.99 516.49 5,969,192.68 350,083.32 0.19 2,634.96 MWD+IFR-AK-CAZ-SC(5) 5,365.66 63.01 12.62 3,523.94 3,453.01 3,380.20 535.91 5,969,273.48 350,104.37 1.58 2,696.57 MWD+IFR-AK-CAZ-SC(5) 5,459.19 62.97 10.81 3,566.42 3,495.49 3,461.78 552.83 5,969,354.70 350,122.92 1.72 2,759.73 MWD+IFR-AK-CAZ-SC(5) 5,553.61 63.32 11.12 3,609.07 3,538.14 3,544.48 568.85 5,969,437.06 350,140.59 0.47 2,824.29 MWD+IFR-AK-CAZ-SC(5) 5,647.87 62.93 9.93 3,651.68 3,580.75 3,627.14 584.21 5,969,519.39 350,157.61 1.20 2,889.14 MWD+IFR-AK-CAZ-SC(5) 5,741.96 63.21 8.40 3,694.30 3,623.37 3,709.96 597.57 5,969,601.91 350,172.62 1.48 2,955.09 MW D+I FR-AK-CAZ-SC(5) 5,836.40 63.11 10.71 3,736.94 3,666.01 3,793.05 611.56 5,969,684.70 350,188.27 2.19 3,020.98 MW D+I FR-AK-CAZ-SC(5) 5,930.92 63.05 12.55 3,779.74 3,708.81 3,875.59 628.55 5,969,766.88 350,206.91 1.74 3,084.94 MWD+IFR-AK-CAZ-SC(5) 6,025.42 63.21 12.06 3,822.45 3,751.52 3,957.95 646.51 5,969,848.85 350,226.52 0.49 3,148.27 MWD+IFR-AK-CAZ-SC(5) 6,118.98 63.17 12.69 3,864.65 3,793.72 4,039.51 664.41 5,969,930.04 350,246.04 0.60 3,210.93 MWD+IFR-AK-CAZ-SC(5) 6,212.97 63.14 14.23 3,907.10 3,836.17 4,121.07 683.92 5,970,011.18 350,267.19 1.46 3,272.79 MWD+IFR-AK-CAZ-SC(5) 6,307.33 63.07 13.39 3,949.78 3,878.85 4,202.79 704.01 5,970,092.47 350,288.91 0.80 3,334.53 MWD+IFR-AK-CAZ-SC(5) 6,401.88 63.05 12.47 3,992.62 3,921.69 4,284.94 722.87 5,970,174.22 350,309.41 0.87 3,397.23 MWD+IFR-AK-CAZ-SC(5) 6,495.08 63.07 11.69 4,034.84 3,963.91 4,366.18 740.26 5,970,255.10 350,328.42 0.75 3,459.86 MWD+IFR-AK-CAZ-SC(5) 6,589.70 63.31 10.63 4,077.52 4,006.59 4,449.03 756.60 5,970,337.60 350,346.42 1.03 3,524.40 MWD+IFR-AK-CAZ-SC(5) 6,683.25 63.10 10.57 4,119.69 4,048.76 4,531.11 771.97 5,970,419.35 350,363.42 0.23 3,588.74 MWD+IFR-AK-CAZ-SC(5) 6,778.11 63.28 10.89 4,162.48 4,091.55 4,614.30 787.73 5,970,502.19 350,380.85 0.36 3,653.86 MWD+IFR-AK-CAZ-SC(5) 6,872.00 63.08 12.00 4,204.84 4,133.91 4,696.42 804.35 5,970,583.96 350,399.12 1.08 3,717.62 MWD+IFR-AK-CAZSC(5) 6,966.53 63.28 11.56 4,247.49 4,176.56 4,779.00 821.58 5,970,666.17 350,417.99 0.47 3,781.50 MWD+IFR-AK-CAZ-SC(5) 7,061.06 63.17 10.95 4,290.08 4,219.15 4,861.77 838.05 5,970,748.59 350,436.12 0.59 3,845.91 MWD+IFR-AK-CAZ-SC(5) 7,152.64 63.11 10.27 4,331.46 4,260.53 4,942.08 853.09 5,970,828.57 350,452.76 0.67 3,908.85 MWD+IFR-AK-CAZ-SC(5) 7,245.91 63.11 11.41 4,373.64 4,302.71 5,023.77 868.73 5,970,909.93 350,470.04 1.09 3,972.72 MWD+IFR-AK-CAZ-SC(5) 7,340.45 63.04 10.97 4,416.45 4,345.52 5,106.46 885.09 5,970,992.27 350,488.05 0.42 4,037.11 MWD+IFR-AK-CAZ-SC(5) 7,434.38 63.15 11.56 4,458.96 4,388.03 5,188.61 901.46 5,971,074.07 350,506.06 0.57 4,101.03 MWD+IFR-AK-CAZ-SC(5) 7,528.64 63.02 12.13 4,501.62 4,430.69 5,270.87 918.71 5,971,155.96 350,524.95 0.56 4,164.61 MWD+IFR-AK-CAZ-SC(5) 7,623.79 63.05 13.32 4,544.77 4,473.84 5,353.59 937.39 5,971,238.28 350,545.29 1.12 4,227.90 MWD+IFR-AK-CAZ-SC(5) 7,718.35 63.11 14.15 4,587.58 4,516.65 5,435.49 957.41 5,971,319.76 350,566.94 0.79 4,289.83 MWD+IFR-AK-CAZ-SC(5) 7,812.20 63.06 14.00 4,630.07 4,559.14 5,516.66 977.76 5,971,400.50 350,588.91 0.15 4,350.96 MWD+IFR-AK-CAZ-SC(5) 7,906.58 63.01 12.84 4,672.86 4,601.93 5,598.49 997.28 5,971,481.91 350,610.07 1.10 4,413.05 MWD+IFR-AK-CAZ-SC(5) 8,001.11 62.99 11.73 4,715.78 4,644.85 5,680.78 1,015.20 5,971,563.82 350,629.64 1.05 4,476.34 MWD+IFR-AK-CAZ-SC(5) 8,095.79 62.95 11.47 4,758.81 4,687.88 5,763.40 1,032.16 5,971,646.08 350,648.25 0.25 4,540.38 MWD+1FR-AK-CAZ-SC(5) 8,189.03 63.15 10.62 4,801.07 4,730.14 5,844.97 1,048.08 5,971,727.31 350,665.80 0.84 4,604.01 MW D+I FR-AK-CAZ-SC(5) 8,284.14 63.21 11.40 4,843.98 4,773.05 5,928.29 1,064.29 5,971,810.28 350,683.67 0.73 4,669.02 MW D+I FR-AK-CAZ-SC(5) 8,378.30 63.17 11.91 4,886.45 4,815.52 6,010.59 1,081.27 5,971,892.22 350,702.30 0.49 4,732.77 MWD+IFR-AK-CAZSC(5) 8,473.66 63.01 12.94 4,929.61 4,858.68 6,093.63 1,099.56 5,971,974.87 350,722.25 0.98 4,796.53 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 2:17:48PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,568.33 63.18 12.37 4,972.45 4,901.52 6,176.00 1,118.06 5,972,056.85 350,742.39 0.57 4,859.61 MWD+IFR-AK-CAZ-SC(5) 8,662.37 62.94 14.00 5,015.06 4,944.13 6,257.63 1,137.18 5,972,138.06 350,763.14 1.57 4,921.73 MWD+IFR-AK-CAZ-SC(5) 8,757.47 63.02 13.62 5,058.26 4,987.33 6,339.90 1,157.40 5,972,219.91 350,785.01 0.37 4,983.88 MWD+IFR-AK-CAZ-SC(5) 8,850.32 62.81 13.05 5,100.54 5,029.61 6,420.33 1,176.47 5,972,299.94 350,805.68 0.59 5,044.99 MWD+IFR-AK-CAZ-SC(5) 8,942.87 63.22 13.04 5,142.53 5,071.60 6,500.68 1,195.08 5,972,379.89 350,825.90 0.44 5,106.23 MWD+IFR-AK-CAZ-SC(5) 9,037.33 62.98 13.61 5,185.27 5,114.34 6,582.65 1,214.50 5,972,461.45 350,846.95 0.60 5,168.51 MWD+IFR-AK-CAZ-SC(5) 9,130.73 63.03 13.66 5,227.67 5,156.74 6,663.53 1,234.12 5,972,541.91 350,868.19 0.07 5,229.74 MWD+IFR-AK-CAZ-SC(5) 9,224.56 62.82 13.68 5,270.37 5,199.44 6,744.71 1,253.86 5,972,622.67 350,889.56 0.22 5,291.17 MWD+IFR-AK-CAZ-SC(5) 9,318.28 62.79 14.34 5,313.20 5,242.27 6,825.59 1,274.04 5,972,703.13 350,911.35 0.63 5,352.13 MWD+IFR-AK-CAZ-SC(5) 9,413.52 63.00 13.23 5,356.60 5,285.67 6,907.92 1,294.24 5,972,785.04 350,933.20 1.06 5,414.35 MWD+IFR-AK-CAZ-SC(5) 9,505.61 62.93 12.09 5,398.46 5,327.53 6,987.96 1,312.22 5,972,864.69 350,952.77 1.11 5,475.63 MWD+IFR-AK-CAZ-SC(5) 9,599.57 63.61 10.72 5,440.72 5,369.79 7,070.22 1,328.81 5,972,946.59 350,971.01 1.49 5,539.53 MWD+IFR-AK-CAZ-SC(5) 9,694.49 63.42 11.25 5,483.05 5,412.12 7,153.62 1,345.00 5,973,029.64 350,988.86 0.54 5,604.63 MWD+IFR-AK-CAZ-SC(5) 9,788.74 63.36 10.30 5,525.27 5,454.34 7,236.40 1,360.75 5,973,112.08 351,006.27 0.90 5,669.39 MWD+IFR-AK-CAZ-SC(5) 9,883.29 63.45 10.34 5,567.60 5,496.67 7,319.57 1,375.90 5,973,194.94 351,023.08 0.10 5,734.79 MWD+IFR-AK-CAZ-SC(5) 9,977.52 62.93 10.48 5,610.10 5,539.17 7,402.29 1,391.10 5,973,277.33 351,039.93 0.57 5,799.77 MWD+IFR-AK-CAZ-SC(5) 10,071.11 63.47 11.53 5,652.30 5,581.37 7,484.29 1,407.04 5,973,358.98 351,057.52 1.16 5,863.76 MWD+IFR-AK-CAZ-SC(5) 10,165.79 62.54 12.25 5,695.27 5,624.34 7,566.84 1,424.42 5,973,441.16 351,076.55 1.19 5,927.54 MWD+IFR-AK-CAZ-SC(5) 10,260.40 62.93 12.52 5,738.61 5,667.68 7,648.98 1,442.46 5,973,522.92 351,096.23 0.48 5,990.63 MWD+IFR-AK-CAZ-SC(5) 10,355.00 63.02 13.29 5,781.60 5,710.67 7,731.12 1,461.28 5,973,604.66 351,116.69 0.73 6,053.35 MWD+IFR-AK-CAZ-SC(5) 10,448.49 62.67 12.54 5,824.27 5,753.34 7,812.20 1,479.87 5,973,685.35 351,136.90 0.81 6,115.25 MWD+IFR-AK-CAZ-SC(5) 10,542.00 63.23 11.91 5,866.79 5,795.86 7,893.60 1,497.51 5,973,766.36 351,156.16 0.85 6,177.89 MWD+IFR-AK-CAZ-SC(5) 10,635.69 63.12 11.90 5,909.07 5,838.14 7,975.41 1,514.76 5,973,847.80 351,175.04 0.12 6,241.08 MWD+IFR-AK-CAZ-SC(5) 10,729.09 63.01 11.68 5,951.38 5,880.45 8,056.92 1,531.77 5,973,928.95 351,193.69 0.24 6,304.12 MWD+IFR-AK-CAZ-SC(5) 10,822.63 63.33 11.26 5,993.60 5,922.67 8,138.72 1,548.37 5,974,010.40 351,211.92 0.53 6,367.62 MWD+IFR-AK-CAZ-SC(5) 10,916.45 63.00 11.60 6,035.95 5,965.02 8,220.78 1,564.96 5,974,092.10 351,230.15 0.48 6,431.35 MWD+IFR-AK-CAZ-SC(5) 11,009.82 63.07 11.26 6,078.29 6,007.36 8,302.34 1,581.45 5,974,173.32 351,248.27 0.33 6,494.69 MWD+IFR-AK-CAZ-SC(5) 11,104.11 63.28 11.03 6,120.84 6,049.91 8,384.90 1,597.71 5,974,255.52 351,266.18 0.31 6,559.01 MWD+IFR-AK-CAZ-SC(5) 11,196.28 63.31 11.83 6,162.26 6,091.33 8,465.61 1,614.03 5,974,335.88 351,284.11 0.78 6,621.69 MWD+IFR-AK-CAZ-SC(5) 11,291.67 62.94 12.01 6,205.38 6,134.45 8,548.86 1,631.60 5,974,418.76 351,303.35 0.42 6,685.98 MWD+IFR-AK-CAZ-SC(5) 11,390.45 63.30 12.57 6,250.04 6,179.11 8,634.95 1,650.36 5,974,504.44 351,323.83 0.62 6,752.18 MWD+IFR-AK-CAZ-SC(5) 11,478.46 62.91 12.77 6,289.86 6,218.93 8,711.52 1,667.57 5,974,580.66 351,342.57 0.49 6,810.81 MWD+IFR-AK-CAZ-SC(5) 11,572.12 63.15 13.21 6,332.33 6,261.40 8,792.86 1,686.34 5,974,661.60 351,362.96 0.49 6,872.86 MWD+IFR-AK-CAZ-SC(5) 11,666.71 63.12 13.25 6,375.08 6,304.15 8,875.00 1,705.65 5,974,743.33 351,383.91 0.05 6,935.34 MWD+IFR-AK-CAZ-SC(5) 11,760.40 63.04 12.17 6,417.50 6,346.57 8,956.49 1,724.03 5,974,824.43 351,403.92 1.03 6,997.70 MWD+IFR-AK-CAZ-SC(5) 11,854.28 63.09 11.07 6,460.02 6,389.09 9,038.47 1,740.89 5,974,906.04 351,422.42 1.05 7,061.23 MWD+IFR-AK-CAZ-SC(5) 11,949.26 62.98 11.98 6,503.09 6,432.16 9,121.42 1,757.80 5,974,988.63 351,440.99 0.86 7,125.57 MWD+IFR-AK-CAZ-SC(5) 12,041.95 63.26 12.06 6,545.00 6,474.07 9,202.28 1,775.02 5,975,069.12 351,459.82 0.31 7,187.95 MWD+IFR-AK-CAZ-SC(5) 12,135.18 63.25 12.35 6,586.96 6,516.03 9,283.65 1,792.62 5,975,150.12 351,479.05 0.28 7,250.59 MWD+IFR-AK-CAZ-SC(5) 12,228.87 62.94 13.17 6,629.35 6,558.42 9,365.14 1,811.07 5,975,231.22 351,499.13 0.85 7,312.91 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 2:17:48PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 12,322.52 63.31 12.62 6,671.69 6,600.76 9,446.57 1,829.71 5,975,312.25 351,519.40 0.66 7,375.09 MWD+IFR-AK-CAZ-SC(5) 12,417.38 63.05 11.60 6,714.49 6,643.56 9,529.34 1,847.47 5,975,394.64 351,538.81 1.00 7,438.87 MWD+IFR-AK-CAZ-SC(5) 12,510.87 63.02 11.00 6,756.88 6,685.95 9,611.05 1,863.80 5,975,476.00 351,556.77 0.57 7,502.42 MWD+IFR-AK-CAZ-SC(5) 12,603.06 63.12 11.24 6,798.63 6,727.70 9,691.70 1,879.65 5,975,556.31 351,574.24 0.26 7,565.28 MWD+IFR-AK-CAZ-SC(5) 12,697.18 62.84 10.81 6,841.39 6,770.46 9,774.00 1,895.69 5,975,638.26 351,591.92 0.50 7,629.48 MWD+IFR-AK-CAZ-SC(5) 12,790.91 63.09 10.44 6,884.00 6,813.07 9,856.05 1,911.08 5,975,719.99 351,608.95 0.44 7,693.79 MWD+IFR-AK-CAZ-SC(5) 12,884.80 63.17 10.47 6,926.43 6,855.50 9,938.41 1,926.28 5,975,802.02 351,625.80 0.09 7,758.46 MWD+IFR-AK-CAZ-SC(5) 12,978.94 63.08 10.31 6,968.99 6,898.06 10,021.01 1,941.42 5,975,884.29 351,642.59 0.18 7,823.35 MWD+IFR-AK-CAZ-SC(5) 13,072.28 63.13 10.29 7,011.21 6,940.28 10,102.91 1,956.31 5,975,965.88 351,659.11 0.06 7,887.77 MWD+IFR-AK-CAZ-SC(5) 13,166.26 63.71 9.53 7,053.26 6,982.33 10,185.70 1,970.77 5,976,048.36 351,675.23 0.95 7,953.17 MWD+IFR-AK-CAZ-SC(5) 13,259.54 65.07 6.32 7,093.59 7,022.66 10,269.00 1,982.35 5,976,131.40 351,688.48 3.43 8,020.41 MWD+IFR-AK-CAZ-SC(5) 13,353.66 65.36 3.42 7,133.05 7,062.12 10,354.13 1,989.60 5,976,216.36 351,697.43 2.81 8,091.35 MWD+IFR-AK-CAZ-SC(5) 13,447.09 65.82 1.29 7,171.67 7,100.74 10,439.13 1,993.09 5,976,301.27 351,702.63 2.13 8,164.00 MWD+IFR-AK-CAZ-SC(5) 13,540.30 67.13 359.30 7,208.87 7,137.94 10,524.59 1,993.53 5,976,386.69 351,704.78 2.41 8,238.53 MWD+IFR-AK-CAZ-SC(5) 13,634.11 69.29 356.39 7,243.70 7,172.77 10,611.61 1,990.24 5,976,473.76 351,703.23 3.69 8,316.24 MWD+IFR-AK-CAZ-SC(5) 13,727.73 71.67 354.23 7,274.98 7,204.05 10,699.54 1,983.01 5,976,561.81 351,697.77 3.35 8,396.65 MWD+IFR-AK-CAZ-SC(5) 13,821.63 73.64 352.97 7,302.98 7,232.05 10,788.61 1,973.01 5,976,651.05 351,689.56 2.46 8,479.39 MWD+IFR-AK-CAZ-SC(5) 13,915.09 74.45 351.64 7,328.67 7,257.74 10,877.66 1,960.98 5,976,740.31 351,679.31 1.62 8,563.11 MWD+IFR-AK-CAZ-SC(5) 14,008.99 77.21 349.76 7,351.65 7,280.72 10,967.49 1,946.26 5,976,830.41 351,666.40 3.52 8,648.81 MWD+IFR-AK-CAZ-SC(5) 14,102.96 79.55 346.72 7,370.58 7,299.65 11,057.58 1,927.49 5,976,920.86 351,649.44 4.03 8,736.71 MWD+IFR-AK-CAZ-SC(5) 14,196.39 82.58 343.00 7,385.10 7,314.17 11,146.64 1,903.38 5,977,010.38 351,627.12 5.10 8,826.29 MWD+IFR-AK-CAZ-SC(5) 14,290.68 85.43 340.62 7,394.95 7,324.02 11,235.71 1,874.11 5,977,100.01 351,599.64 3.93 8,918.39 MWD+IFR-AK-CAZ-SC(5) 14,340.65 86.94 338.69 7,398.27 7,327.34 11,282.46 1,856.78 5,977,147.09 351,583.25 4.91 8,967.68 NOT an Actual Survey'(5) 7-5/8"x 9-7/8"by 11" 14,385.36 88.30 336.96 7,400.13 7,329.20 11,323.82 1,839.91 5,977,188.78 351,567.22 4.91 9,012.03 MWD+IFR-AK-CAZ-SC(5) 14,418.67 89.04 335.19 7,400.90 7,329.97 11,354.26 1,826.41 5,977,219.48 351,554.33 5.76 9,045.20 MWD+IFR-AK-CAZ-SC(5) 14,514.76 91.30 330.78 7,400.61 7,329.68 11,439.84 1,782.78 5,977,305.91 351,512.43 5.16 9,141.20 MWD+IFR-AK-CAZ-SC(5) 14,608.02 90.79 329.62 7,398.91 7,327.98 11,520.75 1,736.44 5,977,387.73 351,467.72 1.36 9,234.43 MWD+IFR-AK-CAZ-SC(5) 14,704.29 91.55 327.85 7,396.95 7,326.02 11,603.02 1,686.49 5,977,470.98 351,419.43 2.00 9,330.60 MWD+IFR-AK-CAZ-SC(5) 14,798.61 91.64 326.93 7,394.32 7,323.39 11,682.44 1,635.68 5,977,551.39 351,370.23 0.98 9,424.70 MWD+IFR-AK-CAZ-SC(5) 14,893.77 91.57 326.08 7,391.66 7,320.73 11,761.76 1,583.18 5,977,631.75 351,319.34 0.90 9,519.53 MWD+IFR-AK-CAZ-SC(5) 14,988.78 91.63 326.49 7,389.00 7,318.07 11,840.76 1,530.47 5,977,711.78 351,268.22 0.44 9,614.18 MWD+IFR-AK-CAZ-SC(5) 15,084.07 90.06 325.97 7,387.60 7,316.67 11,919.96 1,477.51 5,977,792.02 351,216.86 1.74 9,709.13 MWD+IFR-AK-CAZ-SC(5) 15,180.90 90.24 325.84 7,387.34 7,316.41 12,000.15 1,423.23 5,977,873.28 351,164.21 0.23 9,805.57 MWD+IFR-AK-CAZ-SC(5) 15,275.81 90.42 326.79 7,386.80 7,315.87 12,079.12 1,370.59 5,977,953.28 351,113.17 1.02 9,900.16 MWD+IFR-AK-CAZ-SC(5) 15,370.39 89.62 327.37 7,386.77 7,315.84 12,158.51 1,319.19 5,978,033.68 351,063.37 1.04 9,994.52 MWD+IFR-AK-CAZ-SC(5) 15,465.39 89.31 330.83 7,387.65 7,316.72 12,240.01 1,270.41 5,978,116.14 351,016.24 3.66 10,089.45 MWD+IFR-AK-CAZ-SC(5) 15,561.80 89.35 334.66 7,388.78 7,317.85 12,325.70 1,226.27 5,978,202.68 350,973.83 3.97 10,185.79 MWD+IFR-AK-CAZ-SC(5) 15,656.70 89.69 336.14 7,389.58 7,318.65 12,411.98 1,186.77 5,978,289.73 350,936.07 1.60 10,280.41 MWD+IFR-AK-CAZ-SC(5) 15,752.09 89.65 335.78 7,390.12 7,319.19 12,499.09 1,147.91 5,978,377.60 350,898.97 0.38 10,375.44 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 2:17:48PM Page 6 COMPASS 5000.1 Build 74 S • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,848.54 89.76 334.42 7,390.62 7,319.69 12,586.58 1,107.30 5,978,465.87 350,860.12 1.41 10,471.64 MWD+IFR-AK-CAZ-SC(5) 15,944.42 89.77 334.75 7,391.01 7,320.08 12,673.18 1,066.15 5,978,553.27 350,820.72 0.34 10,567.33 MWD+IFR-AK-CAZ-SC(5) 16,039.41 88.83 335.18 7,392.18 7,321.25 12,759.23 1,025.96 5,978,640.11 350,782.26 1.09 10,662.08 MW D+I FR-AK-CAZ-SC(5) 16,135.23 88.80 335.25 7,394.16 7,323.23 12,846.21 985.80 5,978,727.87 350,743.86 0.08 10,757.62 MWD+IFR-AK-CAZ-SC(5) 16,230.34 89.84 333.71 7,395.29 7,324.36 12,932.03 944.83 5,978,814.49 350,704.62 1.95 10,852.55 MWD+IFR-AK-CAZ-SC(5) 16,325.78 89.93 333.41 7,395.48 7,324.55 13,017.49 902.33 5,978,900.77 350,663.85 0.33 10,947.89 MWD+IFR-AK-CAZ-SC(5) 16,419.08 90.79 332.71 7,394.89 7,323.96 13,100.66 860.06 5,978,984.77 350,623.26 1.19 11,041.13 MWD+IFR-AK-CAZ-SC(5) 16,514.32 91.23 332.81 7,393.21 7,322.28 13,185.32 816.48 5,979,070.28 350,581.38 0.47 11,136.31 MWD+IFR-AK-CAZ-SC(5) 16,609.87 91.20 332.59 7,391.19 7,320.26 13,270.21 772.66 5,979,156.03 350,539.28 0.23 11,231.79 MWD+IFR-AK-CAZ-SC(5) 16,705.02 91.23 331.55 7,389.17 7,318.24 13,354.26 728.11 5,979,240.94 350,496.42 1.09 11,326.90 MWD+IFR-AK-CAZ-SC(5) 16,801.11 91.34 331.58 7,387.01 7,316.08 13,438.73 682.36 5,979,326.31 350,452.38 0.12 11,422.97 MWD+IFR-AK-CAZ-SC(5) 16,896.86 90.85 330.99 7,385.18 7,314.25 13,522.69 636.37 5,979,411.17 350,408.08 0.80 11,518.70 MWD+IFR-AK-CAZ-SC(5) 16,991.58 90.00 331.09 7,384.48 7,313.55 13,605.57 590.51 5,979,494.94 350,363.89 0.90 11,613.41 MWD+IFR-AK-CAZ-SC(5) 17,087.48 89.89 330.24 7,384.57 7,313.64 13,689.17 543.53 5,979,579.46 350,318.60 0.89 11,709.31 MWD+IFR-AK-CAZ-SC(5) 17,184.52 90.17 330.30 7,384.52 7,313.59 13,773.43 495.40 5,979,664.67 350,272.18 0.30 11,806.34 MWD+IFR-AK-CAZ-SC(5) 17,278.91 90.80 331.06 7,383.72 7,312.79 13,855.73 449.18 5,979,747.87 350,227.62 1.05 11,900.73 MWD+IFR-AK-CAZ-SC(5) 17,373.47 90.85 331.69 7,382.36 7,311.43 13,938.72 403.89 5,979,831.74 350,184.00 0.67 11,995.27 MWD+IFR-AK-CAZ-SC(5) 17,469.08 90.34 331.37 7,381.37 7,310.44 14,022.77 358.31 5,979,916.68 350,140.12 0.63 12,090.87 MWD+IFR-AK-CAZ-SC(5) 17,563.66 90.41 332.64 7,380.75 7,309.82 14,106.27 313.92 5,980,001.05 350,097.42 1.34 12,185.44 MWD+IFR-AK-CAZ-SC(5) 17,659.45 90.44 333.60 7,380.04 7,309.11 14,191.71 270.61 5,980,087.34 350,055.83 1.00 12,281.16 MWD+IFR-AK-CAZ-SC(5) 17,753.82 90.34 334.97 7,379.40 7,308.47 14,276.73 229.67 5,980,173.15 350,016.60 1.46 12,375.37 MWD+IFR-AK-CAZ-SC(5) 17,849.43 90.37 335.22 7,378.80 7,307.87 14,363.45 189.40 5,980,260.65 349,978.09 0.26 12,470.73 MWD+IFR-AK-CAZ-SC(5) 17,944.77 90.34 335.47 7,378.21 7,307.28 14,450.10 149.63 5,980,348.07 349,940.07 0.26 12,565.79 MWD+IFR-AK-CAZ-SC(5) 18,040.83 90.27 335.89 7,377.70 7,306.77 14,537.63 110.07 5,980,436.38 349,902.27 0.44 12,661.53 MWD+IFR-AK-CAZ-SC(5) 18,134.93 90.00 336.02 7,377.48 7,306.55 14,623.56 71.73 5,980,523.05 349,865.66 0.32 12,755.28 MWD+IFR-AK-CAZ-SC(5) 18,230.43 89.41 335.35 7,377.97 7,307.04 14,710.59 32.41 5,980,610.85 349,828.10 0.93 12,850.46 MWD+IFR-AK-CAZ-SC(5) 18,325.63 88.87 334.66 7,379.40 7,308.47 14,796.86 -7.81 5,980,697.90 349,789.62 0.92 12,945.42 MWD+IFR-AK-CAZ-SC(5) 18,421.05 88.42 334.65 7,381.66 7,310.73 14,883.08 -48.64 5,980,784.91 349,750.52 0.47 13,040.61 MWD+IFR-AK-CAZ-SC(5) 18,515.56 87.84 333.91 7,384.74 7,313.81 14,968.18 -89.64 5,980,870.81 349,711.25 0.99 13,134.92 MWD+IFR-AK-CAZ-SC(5) 18,612.05 87.32 333.45 7,388.82 7,317.89 15,054.58 -132.38 5,980,958.05 349,670.25 0.72 13,231.22 MWD+IFR-AK-CAZ-SC(5) 18,708.10 86.70 333.00 7,393.83 7,322.90 15,140.22 -175.59 5,981,044.53 349,628.76 0.80 13,327.06 MWD+IFR-AK-CAZ-SC(5) 18,802.30 88.73 333.65 7,397.58 7,326.65 15,224.32 -217.84 5,981,129.45 349,588.21 2.26 13,421.10 MWD+IFR-AK-CAZ-SC(5) 18,891.28 92.08 332.15 7,396.95 7,326.02 15,303.52 -258.37 5,981,209.44 349,549.28 4.12 13,510.02 MWD+IFR-AK-CAZ-SC(5) 18,988.75 94.04 331.45 7,391.75 7,320.82 15,389.29 -304.36 5,981,296.11 349,505.02 2.13 13,607.33 MWD+IFR-AK-CAZ-SC(5) 19,087.81 94.15 330.07 7,384.68 7,313.75 15,475.51 -352.62 5,981,383.27 349,458.50 1.39 13,706.14 MWD+IFR-AK-CAZ-SC(5) 19,183.81 94.22 328.41 7,377.67 7,306.74 15,557.78 -401.59 5,981,466.50 349,411.20 1.73 13,801.83 MWD+IFR-AK-CAZ-SC(5) 19,278.08 94.18 328.83 7,370.77 7,299.84 15,638.04 -450.54 5,981,547.72 349,363.86 0.45 13,895.77 MWD+IFR-AK-CAZ-SC(5) 19,372.36 94.15 328.37 7,363.92 7,292.99 15,718.30 -499.54 5,981,628.94 349,316.49 0.49 13,989.72 MWD+IFR-AK-CAZ-SC(5) 19,468.80 93.99 328.43 7,357.07 7,286.14 15,800.24 -549.94 5,981,711.86 349,267.74 0.18 14,085.82 MWD+IFR-AK-CAZ-SC(5) 19,563.70 93.15 327.57 7,351.16 7,280.23 15,880.56 -600.13 5,981,793.17 349,219.18 1.27 14,180.40 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 2:17:48PM Page 7 COMPASS 5000.1 Build 74 • Y • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 19,659.57 93.21 329.81 7,345.84 7,274.91 15,962.34 -649.87 5,981,875.92 349,171.09 2.33 14,276.04 MWD+IFR-AK-CAZ-SC(5) 19,753.65 92.02 329.85 7,341.55 7,270.62 16,043.58 -697.10 5,981,958.09 349,125.50 1.27 14,370.00 MWD+IFR-AK-CAZ-SC(5) 19,849.98 91.13 331.05 7,338.90 7,267.97 16,127.35 -744.59 5,982,042.79 349,079.70 1.55 14,466.28 MWD+IFR-AK-CAZ-SC(5) 19,945.55 90.13 329.96 7,337.85 7,266.92 16,210.53 -791.64 5,982,126.89 349,034.33 1.55 14,561.84 MWD+IFR-AK-CAZ-SC(5) 20,040.96 90.06 330.35 7,337.70 7,266.77 16,293.28 -839.12 5,982,210.57 348,988.52 0.42 14,657.24 MWD+IFR-AK-CAZ-SC(5) 20,135.12 90.13 331.41 7,337.54 7,266.61 16,375.54 -884.95 5,982,293.72 348,944.36 1.13 14,751.40 MWD+IFR-AK-CAZ-SC(5) 20,231.42 90.10 330.96 7,337.35 7,266.42 16,459.92 -931.36 5,982,379.01 348,899.65 0.47 14,847.70 MWD+IFR-AK-CAZ-SC(5) 20,326.61 90.13 332.00 7,337.16 7,266.23 16,543.55 -976.81 5,982,463.53 348,855.89 1.09 14,942.88 MWD+IFR-AK-CAZ-SC(5) 20,421.08 90.03 332.62 7,337.02 7,266.09 16,627.20 -1,020.71 5,982,548.04 348,813.68 0.66 15,037.33 MWD+IFR-AK-CAZ-SC(5) 20,516.76 90.59 333.38 7,336.51 7,265.58 16,712.45 -1,064.15 5,982,634.14 348,771.97 0.99 15,132.95 MWD+IFR-AK-CAZ-SC(5) 20,613.10 90.65 333.89 7,335.46 7,264.53 16,798.77 -1,106.93 5,982,721.28 348,730.93 0.53 15,229.18 MWD+IFR-AK-CAZ-SC(5) 20,707.11 90.58 332.93 7,334.45 7,263.52 16,882.83 -1,149.00 5,982,806.16 348,690.55 1.02 15,323.10 MWD+IFR-AK-CAZ-SC(5) 20,802.44 90.58 333.31 7,333.49 7,262.56 16,967.85 -1,192.10 5,982,892.03 348,649.16 0.40 15,418.36 MWD+IFR-AK-CAZ-SC(5) 20,898.28 90.65 334.48 7,332.46 7,261.53 17,053.91 -1,234.27 5,982,978.91 348,608.73 1.22 15,514.07 MWD+IFR-AK-CAZ-SC(5) 20,939.03 90.72 333.72 7,331.97 7,261.04 17,090.56 -1,252.07 5,983,015.91 348,591.67 1.87 15,554.76 MWD+IFR-AK-CAZ-SC(5) 20,990.00 90.72 333.72 7,331.33 7,260.40 17,136.26 -1,274.63 5,983,062.05 348,570.03 0.00 15,605.67 NOT an Actual Survey 4-112"x 6-1/2" 20,999.00 90.72 333.72 7,331.22 7,260.29 17,144.33 -1,278.62 5,983,070.19 348,566.21 0.00 15,614.66 PROJECTED to TD 11/24/2015 2:17:48PM Page 8 COMPASS 5000.1 Build 74 • • 215146 26497 RECEIVED !'' JV 25 2Lti AO CC- FINAL ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-03 Definitive Survey Report 24 November, 2015 NAD 83 r • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD5-03 Well Position +N/-S 0.00 usft Northing: 5,965,650.92 usfl Latitude: 70°18'49.042 N +E/-W 0.00 usft Easting: 1,489,534.00 usfl Longitude: 151°13'22.493 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 34.10 usft Wellbore CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2015 11/6/2015 17.93 80.83 57,471 Design CD5-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.83 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.83 0.00 0.00 331.00 Survey Program Date 11/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9: 706.73 2,332.23 CD5-03 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/20/2015 9:. 2,393.84 2,393.84 CD5-03 Svy3-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 2,446.61 3,012.81 CD5-03 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1: 3,107.13 3,107.13 CD5-03 SvyS-SLB_MWD-INC_ONLY(C INC+TREND Inclinometer+known azi trend 11/10/2015 1: 3,201.32 20,939.03 CD5-03 Svy6-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/10/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 36.83 0.00 0.00 36.83 -34.10 0.00 0.00 5,965,650.92 1,489,534.00 0.00 0.00 UNDEFINED 115.00 0.78 341.30 115.00 44.07 0.50 -0.17 5,965,651.43 1,489,533.84 0.99 0.52 N NOT an Actual Survey 1) 20"x42" 706.73 6.66 341.30 705.22 634.29 36.84 -12.47 5,965,688.00 1,489,522.27 0.99 38.26 MWD+IFR-AK-CAZ-SC(1) 763.64 9.05 346.48 761.60 690.67 44.32 -14.57 5,965,695.52 1,489,520.32 4.38 45.83 MWD+IFR-AK-CAZ-SC(1) 857.86 10.91 350.45 854.39 783.46 60.32 -17.79 5,965,711.58 1,489,517.43 2.10 61.38 MWD+IFR-AK-CAZ-SC(1) 952.85 13.26 350.82 947.26 876.33 79.94 -21.02 5,965,731.26 1,489,514.60 2.48 80.10 MWD+IFR-AK-CAZ-SC(1) 1,046.87 16.13 351.66 1,038.20 967.27 103.51 -24.63 5,965,754.90 1,489,511.46 3.06 102.47 MWD+IFR-AK-CAZ-SC(1) 1,139.96 18.17 352.74 1,127.15 1,056.22 130.70 -28.34 5,965,782.16 1,489,508.29 2.22 128.06 MWD+IFR-AK-CAZ-SC(1) 1,234.44 19.22 353.12 1,216.64 1,145.71 160.76 -32.07 5,965,812.28 1,489,505.17 1.12 156.15 MWD+IFR-AK-CAZ-SC(1) 11/24/2015 11:55:09AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 1,329.46 21.62 352.72 1,305.68 1,234.75 193.65 -36.16 5,965,845.25 1,489,501.74 2.53 186.90 MWD+IFR-AK-CAZ-SC(1) 1,423.98 22.55 352.28 1,393.27 1,322.34 228.89 -40.80 5,965,880.56 1,489,497.81 1.00 219.97 MWD+IFR-AK-CAZ-SC(1) 1,518.01 23.21 353.74 1,479.90 1,408.97 265.17 -45.24 5,965,916.93 1,489,494.10 0.93 253.86 MWD+IFR-AK-CAZ-SC(1) 1,612.52 26.26 355.12 1,565.73 1,494.80 304.53 -49.05 5,965,956.35 1,489,491.08 3.28 290.12 MWD+IFR-AK-CAZ-SC(1) 1,705.02 29.72 357.69 1,647.40 1,576.47 347.84 -51.72 5,965,999.70 1,489,489.29 3.96 329.30 MWD+IFR-AK-CAZ-SC(1) 1,799.69 33.51 1.37 1,728.01 1,657.08 397.44 -52.04 5,966,049.29 1,489,489.96 4.49 372.83 MWD+IFR-AK-CAZ-SC(1) 1,893.56 36.33 2.16 1,804.97 1,734.04 451.14 -50.37 5,966,102.95 1,489,492.71 3.04 418.99 MWD+IFR-AK-CAZ-SC(1) 1,987.71 39.54 2.93 1,879.22 1,808.29 508.95 -47.79 5,966,160.69 1,489,496.45 3.45 468.31 MWD+IFR-AK-CAZ-SC(1) 2,082.01 42.89 4.47 1,950.15 1,879.22 570.94 -43.75 5,966,222.58 1,489,501.73 3.71 520.57 MWD+IFR-AK-CAZ-SC(1) 2,175.54 46.13 7.05 2,016.84 1,945.91 636.15 -37.13 5,966,287.64 1,489,509.66 3.97 574.39 MWD+IFR-AK-CAZ-SC(1) 2,270.65 49.64 7.72 2,080.62 2,009.69 706.11 -28.05 5,966,357.40 1,489,520.14 3.73 631.18 MWD+IFR-AK-CAZ-SC(1) 2,332.23 52.58 9.87 2,119.28 2,048.35 753.46 -20.71 5,966,404.59 1,489,528.44 5.49 669.03 MWD+IFR-AK-CAZ-SC(1) 2,393.40 53.25 9.01 2,156.17 2,085.24 801.60 -12.71 5,966,452.55 1,489,537.40 1.57 707.25 I NOT an Actual Survey 10-3/4"x 13-1/2" 2,393.84 53.25 9.00 2,156.43 2,085.50 801.94 -12.65 5,966,452.90 1,489,537.47 1.57 707.53 INC+TREND(2) 2,446.61 54.40 8.42 2,187.58 2,116.65 844.05 -6.20 5,966,494.86 1,489,544.76 2.35 741.23 MWD+IFR-AK-CAZ-SC(3) 2,540.41 58.16 9.29 2,239.64 2,168.71 921.12 5.82 5,966,571.67 1,489,558.33 4.08 802.81 MWD+IFR-AK-CAZ-SC(3) 2,635.46 61.10 10.07 2,287.69 2,216.76 1,001.95 19.61 5,966,652.20 1,489,573.74 3.17 866.82 MWD+IFR-AK-CAZ-SC(3) 2,729.01 62.78 12.72 2,331.70 2,260.77 1,082.86 35.94 5,966,732.76 1,489,591.69 3.08 929.67 MWD+IFR-AK-CAZ-SC(3) 2,823.37 63.11 13.13 2,374.62 2,303.69 1,164.76 54.73 5,966,814.26 1,489,612.12 0.52 992.19 MWD+IFR-AK-CAZ-SC(3) 2,918.15 62.77 12.29 2,417.74 2,346.81 1,247.10 73.30 5,966,896.20 1,489,632.34 0.87 1,055.20 MWD+IFR-AK-CAZ-SC(3) 3,012.81 63.22 11.64 2,460.72 2,389.79 1,329.61 90.79 5,966,978.33 1,489,651.48 0.77 1,118.88 MWD+IFR-AK-CAZ-SC(3) 3,107.13 63.22 11.06 2,503.22 2,432.29 1,412.16 107.36 5,967,060.54 1,489,669.71 0.55 1,183.06 INC+TREND(4) 3,201.32 63.27 11.63 2,545.62 2,474.69 1,494.62 123.90 5,967,142.64 1,489,687.90 0.54 1,247.16 MWD+IFR-AK-CAZ-SC(5) 3,294.86 63.22 10.60 2,587.73 2,516.80 1,576.58 140.01 5,967,224.25 1,489,705.65 0.98 1,311.03 MWD+IFR-AK-CAZ-SC(5) 3,389.84 63.34 11.91 2,630.44 2,559.51 1,659.78 156.56 5,967,307.10 1,489,723.87 1.24 1,375.78 MWD+IFR-AK-CAZ-SC(5) 3,484.08 63.36 13.32 2,672.71 2,601.78 1,741.98 174.96 5,967,388.90 1,489,743.91 1.34 1,438.75 MWD+IFR-AK-CAZ-SC(5) 3,578.22 63.29 14.02 2,714.97 2,644.04 1,823.71 194.84 5,967,470.22 1,489,765.43 0.67 1,500.60 MWD+IFR-AK-CAZ-SC(5) 3,672.82 63.21 13.32 2,757.55 2,686.62 1,905.80 214.80 5,967,551.87 1,489,787.04 0.67 1,562.71 MWD+IFR-AK-CAZ-SC(5) 3,767.31 63.20 12.01 2,800.15 2,729.22 1,988.09 233.29 5,967,633.77 1,489,807.18 1.24 1,625.72 MWD+IFR-AK-CAZ-SC(5) 3,861.28 63.17 11.37 2,842.54 2,771.61 2,070.21 250.29 5,967,715.53 1,489,825.82 0.61 1,689.31 MWD+IFR-AK-CAZ-SC(5) 3,955.76 63.38 11.10 2,885.03 2,814.10 2,152.98 266.73 5,967,797.95 1,489,843.92 0.34 1,753.73 MWD+IFR-AK-CAZ-SC(5) 4,049.53 63.36 12.41 2,927.06 2,856.13 2,235.04 283.80 5,967,879.64 1,489,862.64 1.25 1,817.22 MWD+IFR-AK-CAZ-SC(5) 4,143.15 63.31 13.77 2,969.08 2,898.15 2,316.53 302.75 5,967,960.73 1,489,883.22 1.30 1,879.31 MWD+IFR-AK-CAZ-SC(5) 4,236.34 62.87 14.41 3,011.25 2,940.32 2,397.13 322.98 5,968,040.90 1,489,905.06 0.77 1,939.99 MWD+IFR-AK-CAZ-SC(5) 4,330.40 63.05 13.48 3,054.02 2,983.09 2,478.44 343.17 5,968,121.78 1,489,926.88 0.90 2,001.32 MWD+IFR-AK-CAZ-SC(5) 4,425.49 62.81 11.86 3,097.29 3,026.36 2,561.04 361.74 5,968,203.99 1,489,947.10 1.54 2,064.56 MWD+IFR-AK-CAZ-SC(5) 4,519.13 62.92 10.68 3,140.00 3,069.07 2,642.77 378.03 5,968,285.36 1,489,965.03 1.13 2,128.15 MWD+IFR-AK-CAZ-SC(5) 4,613.19 63.14 10.08 3,182.66 3,111.73 2,725.23 393.13 5,968,367.49 1,489,981.78 0.61 2,192.94 MWD+IFR-AK-CAZ-SC(5) 4,706.78 63.07 9.44 3,225.00 3,154.07 2,807.48 407.28 5,968,449.44 1,489,997.58 0.61 2,258.03 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 11:55:09AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,801.41 63.04 10.64 3,267.88 3,196.95 2,890.55 421.99 5,968,532.19 1,490,013.95 1.13 2,323.55 MWD+IFR-AK-CAZ-SC(5) 4,895.24 63.11 12.17 3,310.37 3,239.44 2,972.55 438.53 5,968,613.84 1,490,032.14 1.46 2,387.25 MWD+IFR-AK-CAZ-SC(5) 4,990.46 62.94 13.50 3,353.56 3,282.63 3,055.29 457.38 5,968,696.17 1,490,052.65 1.26 2,450.47 MWD+IFR-AK-CAZ-SC(5) 5,084.21 63.08 12.56 3,396.11 3,325.18 3,136.67 476.21 5,968,777.16 1,490,073.11 0.91 2,512.53 MWD+IFR-AK-CAZ-SC(5) 5,177.74 62.91 14.45 3,438.58 3,367.65 3,217.70 495.67 5,968,857.77 1,490,094.19 1.81 2,573.96 MWD+IFR-AK-CAZSC(5) 5,271.95 63.01 14.28 3,481.41 3,410.48 3,298.99 516.49 5,968,938.62 1,490,116.64 0.19 2,634.96 MWD+IFR-AK-CAZ-SC(5) 5,365.66 63.01 12.62 3,523.94 3,453.01 3,380.20 535.91 5,969,019.41 1,490,137.69 1.58 2,696.57 MWD+IFR-AK-CAZ-SC(5) 5,459.19 62.97 10.81 3,566.42 3,495.49 3,461.78 552.83 5,969,100.64 1,490,156.24 1.72 2,759.73 MWD+IFR-AK-CAZ-SC(5) 5,553.61 63.32 11.12 3,609.07 3,538.14 3,544.48 568.85 5,969,182.99 1,490,173.92 0.47 2,824.29 MWD+IFR-AK-CAZ-SC(5) 5,647.87 62.93 9.93 3,651.68 3,580.75 3,627.14 584.21 5,969,265.32 1,490,190.94 1.20 2,889.14 MWD+IFR-AK-CAZ-SC(5) 5,741.96 63.21 8.40 3,694.30 3,623.37 3,709.96 597.57 5,969,347.85 1,490,205.96 1.48 2,955.09 MWD+IFR-AK-CAZ-SC(5) 5,836.40 63.11 10.71 3,736.94 3,666.01 3,793.05 611.56 5,969,430.63 1,490,221.61 2.19 3,020.98 MWD+IFR-AK-CAZ-SC(5) 5,930.92 63.05 12.55 3,779.74 3,708.81 3,875.59 628.55 5,969,512.81 1,490,240.25 1.74 3,084.94 MWD+IFR-AK-CAZ-SC(5) 6,025.42 63.21 12.06 3,822.45 3,751.52 3,957.95 646.51 5,969,594.79 1,490,259.86 0.49 3,148.27 MWD+IFR-AK-CAZ-SC(5) 6,118.98 63.17 12.69 3,864.65 3,793.72 4,039.51 664.41 5,969,675.97 1,490,279.39 0.60 3,210.93 MWD+IFR-AK-CAZ-SC(5) 6,212.97 63.14 14.23 3,907.10 3,836.17 4,121.07 683.92 5,969,757.10 1,490,300.55 1.46 3,272.79 MWD+IFR-AK-CAZ-SC(5) 6,307.33 63.07 13.39 3,949.78 3,878.85 4,202.79 704.01 5,969,838.40 1,490,322.27 0.80 3,334.53 MWD+IFR-AK-CAZ-SC(5) 6,401.88 63.05 12.47 3,992.62 3,921.69 4,284.94 722.87 5,969,920.15 1,490,342.78 0.87 3,397.23 MWD+IFR-AK-CAZ-SC(5) 6,495.08 63.07 11.69 4,034.84 3,963.91 4,366.18 740.26 5,970,001.02 1,490,361.79 0.75 3,459.86 MWD+IFR-AK-CAZ-SC(5) 6,589.70 63.31 10.63 4,077.52 4,006.59 4,449.03 756.60 5,970,083.52 1,490,379.80 1.03 3,524.40 MWD+IFR-AK-CAZ-SC(5) 6,683.25 63.10 10.57 4,119.69 4,048.76 4,531.11 771.97 5,970,165.27 1,490,396.80 0.23 3,588.74 MWD+IFR-AK-CAZ-SC(5) 6,778.11 63.28 10.89 4,162.48 4,091.55 4,614.30 787.73 5,970,248.11 1,490,414.23 0.36 3,653.86 MWD+IFR-AK-CAZ-SC(5) 6,872.00 63.08 12.00 4,204.84 4,133.91 4,696.42 804.35 5,970,329.88 1,490,432.50 1.08 3,717.62 MWD+IFR-AK-CAZ-SC(5) 6,966.53 63.28 11.56 4,247.49 4,176.56 4,779.00 821.58 5,970,412.09 1,490,451.38 0.47 3,781.50 MWD+IFR-AK-CAZ-SC(5) 7,061.06 63.17 10.95 4,290.08 4,219.15 4,861.77 838.05 5,970,494.51 1,490,469.51 0.59 3,845.91 MWD+IFR-AK-CAZ-SC(5) 7,152.64 63.11 10.27 4,331.46 4,260.53 4,942.08 853.09 5,970,574.49 1,490,486.16 0.67 3,908.85 MWD+IFR-AK-CAZ-SC(5) 7,245.91 63.11 11.41 4,373.64 4,302.71 5,023.77 868.73 5,970,655.85 1,490,503.44 1.09 3,972.72 MWD+IFR-AK-CAZ-SC(5) 7,340.45 63.04 10.97 4,416.45 4,345.52 5,106.46 885.09 5,970,738.19 1,490,521.46 0.42 4,037.11 MWD+IFR-AK-CAZ-SC(5) 7,434.38 63.15 11.56 4,458.96 4,388.03 5,188.61 901.46 5,970,819.99 1,490,539.47 0.57 4,101.03 MWD+IFR-AK-CAZ-SC(5) 7,528.64 63.02 12.13 4,501.62 4,430.69 5,270.87 918.71 5,970,901.88 1,490,558.37 0.56 4,164.61 MWD+IFR-AK-CAZ-SC(5) 7,623.79 63.05 13.32 4,544.77 4,473.84 5,353.59 937.39 5,970,984.20 1,490,578.70 1.12 4,227.90 MWD+IFR-AK-CAZ-SC(5) 7,718.35 63.11 14.15 4,587.58 4,516.65 5,435.49 957.41 5,971,065.67 1,490,600.36 0.79 4,289.83 MWD+IFR-AK-CAZ-SC(5) 7,812.20 63.06 14.00 4,630.07 4,559.14 5,516.66 977.76 5,971,146.41 1,490,622.34 0.15 4,350.96 MWD+IFR-AK-CAZ-SC(5) 7,906.58 63.01 12.84 4,672.86 4,601.93 5,598.49 997.28 5,971,227.82 1,490,643.50 1.10 4,413.05 MWD+IFR-AK-CAZSC(5) 8,001.11 62.99 11.73 4,715.78 4,644.85 5,680.78 1,015.20 5,971,309.73 1,490,663.07 1.05 4,476.34 MWD+IFR-AK-CAZ-SC(5) 8,095.79 62.95 11.47 4,758.81 4,687.88 5,763.40 1,032.16 5,971,391.99 1,490,681.69 0.25 4,540.38 MWD+IFR-AK-CAZ-SC(5) 8,189.03 63.15 10.62 4,801.07 4,730.14 5,844.97 1,048.08 5,971,473.22 1,490,699.24 0.84 4,604.01 MWD+IFR-AK-CAZ-SC(5) 8,284.14 63.21 11.40 4,843.98 4,773.05 5,928.29 1,064.29 5,971,556.18 1,490,717.12 0.73 4,669.02 MW D+I FR-AK-CAZ-SC(5) 8,378.30 63.17 11.91 4,886.45 4,815.52 6,010.59 1,081.27 5,971,638.13 1,490,735.75 0.49 4,732.77 MWD+IFR-AK-CAZ-SC(5) 8,473.66 63.01 12.94 4,929.61 4,858.68 6,093.63 1,099.56 5,971,720.78 1,490,755.71 0.98 4,796.53 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 11:55:09AM Page 4 COMPASS 5000.1 Build 74 • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 8,568.33 63.18 12.37 4,972.45 4,901.52 6,176.00 1,118.06 5,971,802.75 1,490,775.85 0.57 4,859.61 MWD+IFR-AK-CAZ-SC(5) 8,662.37 62.94 14.00 5,015.06 4,944.13 6,257.63 1,137.18 5,971,883.97 1,490,796.61 1.57 4,921.73 MWD+I FR-AK-CAZ-SC(5) 8,757.47 63.02 13.62 5,058.26 4,987.33 6,339.90 1,157.40 5,971,965.81 1,490,818.48 0.37 4,983.88 MWD+IFR-AK-CAZ-SC(5) 8,850.32 62.81 13.05 5,100.54 5,029.61 6,420.33 1,176.47 5,972,045.84 1,490,839.16 0.59 5,044.99 MWD+I FR-AK-CAZ-SC(5) 8,942.87 63.22 13.04 5,142.53 5,071.60 6,500.68 1,195.08 5,972,125.79 1,490,859.38 0.44 5,106.23 MWD+IFR-AK-CAZ-SC(5) 9,037.33 62.98 13.61 5,185.27 5,114.34 6,582.65 1,214.50 5,972,207.35 1,490,880.44 0.60 5,168.51 MWD+IFR-AK-CAZ-SC(5) 9,130.73 63.03 13.66 5,227.67 5,156.74 6,663.53 1,234.12 5,972,287.81 1,490,901.68 0.07 5,229.74 MWD+IFR-AK-CAZ-SC(5) 9,224.56 62.82 13.68 5,270.37 5,199.44 6,744.71 1,253.86 5,972,368.57 1,490,923.05 0.22 5,291.17 MWD+1FR-AK-CAZ-SC(5) 9,318.28 62.79 14.34 5,313.20 5,242.27 6,825.59 1,274.04 5,972,449.02 1,490,944.85 0.63 5,352.13 MWD+IFR-AK-CAZ-SC(5) 9,413.52 63.00 13.23 5,356.60 5,285.67 6,907.92 1,294.24 5,972,530.93 1,490,966.70 1.06 5,414.35 MWD+IFR-AK-CAZ-SC(5) 9,505.61 62.93 12.09 5,398.46 5,327.53 6,987.96 1,312.22 5,972,610.58 1,490,986.28 1.11 5,475.63 MWD+1FR-AK-CAZ-SC(5) 9,599.57 63.61 10.72 5,440.72 5,369.79 7,070.22 1,328.81 5,972,692.48 1,491,004.51 1.49 5,539.53 MWD+IFR-AK-CAZ-SC(5) 9,694.49 63.42 11.25 5,483.05 5,412.12 7,153.62 1,345.00 5,972,775.53 1,491,022.37 0.54 5,604.63 MWD+1FR-AK-CAZ-SC(5) 9,788.74 63.36 10.30 5,525.27 5,454.34 7,236.40 1,360.75 5,972,857.98 1,491,039.79 0.90 5,669.39 MWD+IFR-AK-CAZ-SC(5) 9,883.29 63.45 10.34 5,567.60 5,496.67 7,319.57 1,375.90 5,972,940.83 1,491,056.60 0.10 5,734.79 MWD+IFR-AK-CAZ-SC(5) 9,977.52 62.93 10.48 5,610.10 5,539.17 7,402.29 1,391.10 5,973,023.21 1,491,073.45 0.57 5,799.77 MWD+IFR-AK-CAZ-SC(5) 10,071.11 63.47 11.53 5,652.30 5,581.37 7,484.29 1,407.04 5,973,104.87 1,491,091.05 1.16 5,863.76 MWD+IFR-AK-CAZ-SC(5) 10,165.79 62.54 12.25 5,695.27 5,624.34 7,566.84 1,424.42 5,973,187.05 1,491,110.08 1.19 5,927.54 MWD+IFR-AK-CAZ-SC(5) 10,260.40 62.93 12.52 5,738.61 5,667.68 7,648.98 1,442.46 5,973,268.81 1,491,129.76 0.48 5,990.63 MWD+IFR-AK-CAZ-SC(5) 10,355.00 63.02 13.29 5,781.60 5,710.67 7,731.12 1,461.28 5,973,350.55 1,491,150.23 0.73 6,053.35 MWD+IFR-AK-CAZ-SC(5) 10,448.49 62.67 12.54 5,824.27 5,753.34 7,812.20 1,479.87 5,973,431.23 1,491,170.45 0.81 6,115.25 MWD+1FR-AK-CAZ-SC(5) 10,542.00 63.23 11.91 5,866.79 5,795.86 7,893.60 1,497.51 5,973,512.25 1,491,189.71 0.85 6,177.89 MWD+1FR-AK-CAZ-SC(5) 10,635.69 63.12 11.90 5,909.07 5,838.14 7,975.41 1,514.76 5,973,593.69 1,491,208.60 0.12 6,241.08 MWD+IFR-AK-CAZ-SC(5) 10,729.09 63.01 11.68 5,951.38 5,880.45 8,056.92 1,531.77 5,973,674.83 1,491,227.24 0.24 6,304.12 MWD+IFR-AK-CAZ-SC(5) 10,822.63 63.33 11.26 5,993.60 5,922.67 8,138.72 1,548.37 5,973,756.28 1,491,245.48 0.53 6,367.62 MWD+1FR-AK-CAZ-SC(5) 10,916.45 63.00 11.60 6,035.95 5,965.02 8,220.78 1,564.96 5,973,837.98 1,491,263.71 0.48 6,431.35 MW D+I FR-AK-CAZ-SC(5) 11,009.82 63.07 11.26 6,078.29 6,007.36 8,302.34 1,581.45 5,973,919.19 1,491,281.84 0.33 6,494.69 MWD+I FR-AK-CAZ-SC(5) 11,104.11 63.28 11.03 6,120.84 6,049.91 8,384.90 1,597.71 5,974,001.40 1,491,299.76 0.31 6,559.01 MW D+I FR-AK-CAZ-SC(5) 11,196.28 63.31 11.83 6,162.26 6,091.33 8,465.61 1,614.03 5,974,081.76 1,491,317.69 0.78 6,621.69 MWD+I FR-AK-CAZ-SC(5) 11,291.67 62.94 12.01 6,205.38 6,134.45 8,548.86 1,631.60 5,974,164.63 1,491,336.94 0.42 6,685.98 MWD+IFR-AK-CAZ-SC(5) 11,390.45 63.30 12.57 6,250.04 6,179.11 8,634.95 1,650.36 5,974,250.32 1,491,357.42 0.62 6,752.18 MWD+IFR-AK-CAZ-SC(5) 11,478.46 62.91 12.77 6,289.86 6,218.93 8,711.52 1,667.57 5,974,326.53 1,491,376.17 0.49 6,810.81 MWD+1FR-AK-CAZ-SC(5) 11,572.12 63.15 13.21 6,332.33 6,261.40 8,792.86 1,686.34 5,974,407.47 1,491,396.56 0.49 6,872.86 MWD+IFR-AK-CAZ-SC(5) 11,666.71 63.12 13.25 6,375.08 6,304.15 8,875.00 1,705.65 5,974,489.20 1,491,417.51 0.05 6,935.34 MWD+IFR-AK-CAZ-SC(5) 11,760.40 63.04 12.17 6,417.50 6,346.57 8,956.49 1,724.03 5,974,570.30 1,491,437.53 1.03 6,997.70 MWD+I FR-AK-CAZ-SC(5) 11,854.28 63.09 11.07 6,460.02 6,389.09 9,038.47 1,740.89 5,974,651.91 1,491,456.03 1.05 7,061.23 MWD+I FR-AK-CAZ-SC(5) 11,949.26 62.98 11.98 6,503.09 6,432.16 9,121.42 1,757.80 5,974,734.50 1,491,474.60 0.86 7,125.57 MWD+IFR-AK-CAZ-SC(5) 12,041.95 63.26 12.06 6,545.00 6,474.07 9,202.28 1,775.02 5,974,814.99 1,491,493.44 0.31 7,187.95 MW D+I FR-AK-CAZ-SC(5) 12,135.18 63.25 12.35 6,586.96 6,516.03 9,283.65 1,792.62 5,974,895.99 1,491,512.67 0.28 7,250.59 MWD+IFR-AK-CAZ-SC(5) 12,228.87 62.94 13.17 6,629.35 6,558.42 9,365.14 1,811.07 5,974,977.08 1,491,532.76 0.85 7,312.91 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 11:55:09AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,322.52 63.31 12.62 6,671.69 6,600.76 9,446.57 1,829.71 5,975,058.11 1,491,553.03 0.66 7,375.09 MWD+IFR-AK-CAZ-SC(5) 12,417.38 63.05 11.60 6,714.49 6,643.56 9,529.34 1,847.47 5,975,140.50 1,491,572.45 1.00 7,438.87 MWD+IFR-AK-CAZ-SC(5) 12,510.87 63.02 11.00 6,756.88 6,685.95 9,611.05 1,863.80 5,975,221.86 1,491,590.41 0.57 7,502.42 MWD+IFR-AK-CAZ-SC(5) 12,603.06 63.12 11.24 6,798.63 6,727.70 9,691.70 1,879.65 5,975,302.17 1,491,607.88 0.26 7,565.28 MWD+IFR-AK-CAZ-SC(5) 12,697.18 62.84 10.81 6,841.39 6,770.46 9,774.00 1,895.69 5,975,384.12 1,491,625.56 0.50 7,629.48 MWD+IFR-AK-CAZ-SC(5) 12,790.91 63.09 10.44 6,884.00 6,813.07 9,856.05 1,911.08 5,975,465.85 1,491,642.60 0.44 7,693.79 MWD+IFR-AK-CAZ-SC(5) 12,884.80 63.17 10.47 6,926.43 6,855.50 9,938.41 1,926.28 5,975,547.88 1,491,659.45 0.09 7,758.46 MWD+IFR-AK-CAZ-SC(5) 12,978.94 63.08 10.31 6,968.99 6,898.06 10,021.01 1,941.42 5,975,630.15 1,491,676.25 0.18 7,823.35 MWD+IFR-AK-CAZ-SC(5) 13,072.28 63.13 10.29 7,011.21 6,940.28 10,102.91 1,956.31 5,975,711.73 1,491,692.78 0.06 7,887.77 MWD+IFR-AK-CAZ-SC(5) 13,166.26 63.71 9.53 7,053.26 6,982.33 10,185.70 1,970.77 5,975,794.21 1,491,708.90 0.95 7,953.17 MWD+IFR-AK-CAZ-SC(5) 13,259.54 65.07 6.32 7,093.59 7,022.66 10,269.00 1,982.35 5,975,877.25 1,491,722.15 3.43 8,020.41 MWD+IFR-AK-CAZ-SC(5) 13,353.66 65.36 3.42 7,133.05 7,062.12 10,354.13 1,989.60 5,975,962.21 1,491,731.11 2.81 8,091.35 MWD+IFR-AK-CAZ-SC(5) 13,447.09 65.82 1.29 7,171.67 7,100.74 10,439.13 1,993.09 5,976,047.12 1,491,736.31 2.13 8,164.00 MWD+IFR-AK-CAZ-SC(5) 13,540.30 67.13 359.30 7,208.87 7,137.94 10,524.59 1,993.53 5,976,132.54 1,491,738.46 2.41 8,238.53 MWD+IFR-AK-CAZ-SC(5) 13,634.11 69.29 356.39 7,243.70 7,172.77 10,611.61 1,990.24 5,976,219.61 1,491,736.92 3.69 8,316.24 MWD+IFR-AK-CAZ-SC(5) 13,727.73 71.67 354.23 7,274.98 7,204.05 10,699.54 1,983.01 5,976,307.66 1,491,731.46 3.35 8,396.65 MWD+IFR-AK-CAZ-SC(5) 13,821.63 73.64 352.97 7,302.98 7,232.05 10,788.61 1,973.01 5,976,396.90 1,491,723.26 2.46 8,479.39 MWD+IFR-AK-CAZ-SC(5) 13,915.09 74.45 351.64 7,328.67 7,257.74 10,877.66 1,960.98 5,976,486.17 1,491,713.02 1.62 8,563.11 MWD+IFR-AK-CAZ-SC(5) 14,008.99 77.21 349.76 7,351.65 7,280.72 10,967.49 1,946.26 5,976,576.27 1,491,700.11 3.52 8,648.81 MWD+IFR-AK-CAZ-SC(5) 14,102.96 79.55 346.72 7,370.58 7,299.65 11,057.58 1,927.49 5,976,666.72 1,491,683.16 4.03 8,736.71 MWD+IFR-AK-CAZ-SC(5) 14,196.39 82.58 343.00 7,385.10 7,314.17 11,146.64 1,903.38 5,976,756.24 1,491,660.84 5.10 8,826.29 MWD+IFR-AK-CAZ-SC(5) 14,290.68 85.43 340.62 7,394.95 7,324.02 11,235.71 1,874.11 5,976,845.87 1,491,633.37 3.93 8,918.39 MWD+IFR-AK-CAZ-SC(5) 14,340.65 86.94 338.69 7,398.27 7,327.34 11,282.46 1,856.78 5,976,892.95 1,491,616.97 4.91 8,967.68 NOT an Actual Survey (5) 7-5/8"x 9-718"by 11" 14,385.36 88.30 336.96 7,400.13 7,329.20 11,323.82 1,839.91 5,976,934.64 1,491,600.95 4.91 9,012.03 MWD+IFR-AK-CAZ-SC(5) 14,418.67 89.04 335.19 7,400.90 7,329.97 11,354.26 1,826.41 5,976,965.35 1,491,588.06 5.76 9,045.20 MWD+IFR-AK-CAZ-SC(5) 14,514.76 91.30 330.78 7,400.61 7,329.68 11,439.84 1,782.78 5,977,051.78 1,491,546.16 5.16 9,141.20 MWD+IFR-AK-CAZ-SC(5) 14,608.02 90.79 329.62 7,398.91 7,327.98 11,520.75 1,736.44 5,977,133.60 1,491,501.46 1.36 9,234.43 MWD+IFR-AK-CAZ-SC(5) 14,704.29 91.55 327.85 7,396.95 7,326.02 11,603.02 1,686.49 5,977,216.85 1,491,453.17 2.00 9,330.60 MWD+IFR-AK-CAZ-SC(5) 14,798.61 91.64 326.93 7,394.32 7,323.39 11,682.44 1,635.68 5,977,297.27 1,491,403.97 0.98 9,424.70 MWD+IFR-AK-CAZ-SC(5) 14,893.77 91.57 326.08 7,391.66 7,320.73 11,761.76 1,583.18 5,977,377.62 1,491,353.09 0.90 9,519.53 MWD+IFR-AK-CAZ-SC(5) 14,988.78 91.63 326.49 7,389.00 7,318.07 11,840.76 1,530.47 5,977,457.66 1,491,301.97 0.44 9,614.18 MWD+IFR-AK-CAZ-SC(5) 15,084.07 90.06 325.97 7,387.60 7,316.67 11,919.96 1,477.51 5,977,537.90 1,491,250.62 1.74 9,709.13 MWD+IFR-AK-CAZ-SC(5) 15,180.90 90.24 325.84 7,387.34 7,316.41 12,000.15 1,423.23 5,977,619.16 1,491,197.97 0.23 9,805.57 MWD+IFR-AK-CAZ-SC(5) 15,275.81 90.42 326.79 7,386.80 7,315.87 12,079.12 1,370.59 5,977,699.17 1,491,146.93 1.02 9,900.16 MWD+IFR-AK-CAZ-SC(5) 15,370.39 89.62 327.37 7,386.77 7,315.84 12,158.51 1,319.19 5,977,779.57 1,491,097.14 1.04 9,994.52 MWD+IFR-AK-CAZ-SC(5) 15,465.39 89.31 330.83 7,387.65 7,316.72 12,240.01 1,270.41 5,977,862.03 1,491,050.01 3.66 10,089.45 MWD+IFR-AK-CAZ-SC(5) 15,561.80 89.35 334.66 7,388.78 7,317.85 12,325.70 1,226.27 5,977,948.58 1,491,007.61 3.97 10,185.79 MWD+IFR-AK-CAZ-SC(5) 15,656.70 89.69 336.14 7,389.58 7,318.65 12,411.98 1,186.77 5,978,035.63 1,490,969.85 1.60 10,280.41 MWD+IFR-AK-CAZ-SC(5) 15,752.09 89.65 335.78 7,390.12 7,319.19 12,499.09 1,147.91 5,978,123.50 1,490,932.75 0.38 10,375.44 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 11:55:09AM Page 6 COMPASS 5000.1 Build 74 • i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 15,848.54 89.76 334.42 7,390.62 7,319.69 12,586.58 1,107.30 5,978,211.77 1,490,893.91 1.41 10,471.64 MWD+IFR-AK-CAZ-SC(5) 15,944.42 89.77 334.75 7,391.01 7,320.08 12,673.18 1,066.15 5,978,299.17 1,490,854.52 0.34 10,567.33 MWD+IFR-AK-CAZ-SC(5) 16,039.41 88.83 335.18 7,392.18 7,321.25 12,759.23 1,025.96 5,978,386.02 1,490,816.06 1.09 10,662.08 MWD+IFR-AK-CAZ-SC(5) 16,135.23 88.80 335.25 7,394.16 7,323.23 12,846.21 985.80 5,978,473.77 1,490,777.66 0.08 10,757.62 MWD+IFR-AK-CAZ-SC(5) 16,230.34 89.84 333.71 7,395.29 7,324.36 12,932.03 944.83 5,978,560.39 1,490,738.43 1.95 10,852.55 MWD+IFR-AK-CAZ-SC(5) 16,325.78 89.93 333.41 7,395.48 7,324.55 13,017.49 902.33 5,978,646.68 1,490,697.66 0.33 10,947.89 MWD+IFR-AK-CAZ-SC(5) 16,419.08 90.79 332.71 7,394.89 7,323.96 13,100.66 860.06 5,978,730.68 1,490,657.07 1.19 11,041.13 MWD+IFR-AK-CAZ-SC(5) 16,514.32 91.23 332.81 7,393.21 7,322.28 13,185.32 816.48 5,978,816.20 1,490,615.20 0.47 11,136.31 MWD+IFR-AK-CAZ-SC(5) 16,609.87 91.20 332.59 7,391.19 7,320.26 13,270.21 772.66 5,978,901.94 1,490,573.11 0.23 11,231.79 MWD+IFR-AK-CAZ-SC(5) 16,705.02 91.23 331.55 7,389.17 7,318.24 13,354.26 728.11 5,978,986.86 1,490,530.25 1.09 11,326.90 MWD+IFR-AK-CAZ-SC(5) 16,801.11 91.34 331.58 7,387.01 7,316.08 13,438.73 682.36 5,979,072.23 1,490,486.22 0.12 11,422.97 MWD+IFR-AK-CAZ-SC(5) 16,896.86 90.85 330.99 7,385.18 7,314.25 13,522.69 636.37 5,979,157.09 1,490,441.92 0.80 11,518.70 MWD+IFR-AK-CAZ-SC(5) 16,991.58 90.00 331.09 7,384.48 7,313.55 13,605.57 590.51 5,979,240.86 1,490,397.74 0.90 11,613.41 MWD+IFR-AK-CAZ-SC(5) 17,087.48 89.89 330.24 7,384.57 7,313.64 13,689.17 543.53 5,979,325.39 1,490,352.45 0.89 11,709.31 MWD+IFR-AK-CAZ-SC(5) 17,184.52 90.17 330.30 7,384.52 7,313.59 13,773.43 495.40 5,979,410.60 1,490,306.03 0.30 11,806.34 MWD+IFR-AK-CAZ-SC(5) 17,278.91 90.80 331.06 7,383.72 7,312.79 13,855.73 449.18 5,979,493.80 1,490,261.48 1.05 11,900.73 MWD+IFR-AK-CAZ-SC(5) 17,373.47 90.85 331.69 7,382.36 7,311.43 13,938.72 403.89 5,979,577.68 1,490,217.86 0.67 11,995.27 MWD+IFR-AK-CAZ-SC(5) 17,469.08 90.34 331.37 7,381.37 7,310.44 14,022.77 358.31 5,979,662.61 1,490,173.99 0.63 12,090.87 MWD+IFR-AK-CAZ-SC(5) 17,563.66 90.41 332.64 7,380.75 7,309.82 14,106.27 313.92 5,979,746.99 1,490,131.29 1.34 12,185.44 MWD+IFR-AK-CAZ-SC(5) 17,659.45 90.44 333.60 7,380.04 7,309.11 14,191.71 270.61 5,979,833.28 1,490,089.71 1.00 12,281.16 MWD+IFR-AK-CAZ-SC(5) 17,753.82 90.34 334.97 7,379.40 7,308.47 14,276.73 229.67 5,979,919.10 1,490,050.48 1.46 12,375.37 MWD+IFR-AK-CAZ-SC(5) 17,849.43 90.37 335.22 7,378.80 7,307.87 14,363.45 189.40 5,980,006.60 1,490,011.97 0.26 12,470.73 MWD+IFR-AK-CAZ-SC(5) 17,944.77 90.34 335.47 7,378.21 7,307.28 14,450.10 149.63 5,980,094.02 1,489,973.96 0.26 12,565.79 MWD+IFR-AK-CAZ-SC(5) 18,040.83 90.27 335.89 7,377.70 7,306.77 14,537.63 110.07 5,980,182.32 1,489,936.17 0.44 12,661.53 MWD+IFR-AK-CAZ-SC(5) 18,134.93 90.00 336.02 7,377.48 7,306.55 14,623.56 71.73 5,980,269.01 1,489,899.56 0.32 12,755.28 MWD+IFR-AK-CAZ-SC(5) 18,230.43 89.41 335.35 7,377.97 7,307.04 14,710.59 32.41 5,980,356.80 1,489,862.00 0.93 12,850.46 MWD+IFR-AK-CAZ-SC(5) 18,325.63 88.87 334.66 7,379.40 7,308.47 14,796.86 -7.81 5,980,443.86 1,489,823.52 0.92 12,945.42 MWD+IFR-AK-CAZ-SC(5) 18,421.05 88.42 334.65 7,381.66 7,310.73 14,883.08 -48.64 5,980,530.86 1,489,784.43 0.47 13,040.61 MWD+IFR-AK-CAZ-SC(5) 18,515.56 87.84 333.91 7,384.74 7,313.81 14,968.18 -89.64 5,980,616.76 1,489,745.16 0.99 13,134.92 MWD+IFR-AK-CAZ-SC(5) 18,612.05 87.32 333.45 7,388.82 7,317.89 15,054.58 -132.38 5,980,704.01 1,489,704.17 0.72 13,231.22 MWD+IFR-AK-CAZ-SC(5) 18,708.10 86.70 333.00 7,393.83 7,322.90 15,140.22 -175.59 5,980,790.49 1,489,662.69 0.80 13,327.06 MWD+IFR-AK-CAZ-SC(5) 18,802.30 88.73 333.65 7,397.58 7,326.65 15,224.32 -217.84 5,980,875.42 1,489,622.14 2.26 13,421.10 MWD+IFR-AK-CAZ-SC(5) 18,891.28 92.08 332.15 7,396.95 7,326.02 15,303.52 -258.37 5,980,955.40 1,489,583.21 4.12 13,510.02 MWD+IFR-AK-CAZ-SC(5) 18,988.75 94.04 331.45 7,391.75 7,320.82 15,389.29 -304.36 5,981,042.08 1,489,538.96 2.13 13,607.33 MWD+IFR-AK-CAZ-SC(5) 19,087.81 94.15 330.07 7,384.68 7,313.75 15,475.51 -352.62 5,981,129.24 1,489,492.44 1.39 13,706.14 MWD+IFR-AK-CAZ-SC(5) 19,183.81 94.22 328.41 7,377.67 7,306.74 15,557.78 -401.59 5,981,212.47 1,489,445.14 1.73 13,801.83 MWD+IFR-AK-CAZ-SC(5) 19,278.08 94.18 328.83 7,370.77 7,299.84 15,638.04 -450.54 5,981,293.70 1,489,397.81 0.45 13,895.77 MWD+IFR-AK-CAZ-SC(5) 19,372.36 94.15 328.37 7,363.92 7,292.99 15,718.30 -499.54 5,981,374.92 1,489,350.45 0.49 13,989.72 MWD+IFR-AK-CAZ-SC(5) 19,468.80 93.99 328.43 7,357.07 7,286.14 15,800.24 -549.94 5,981,457.85 1,489,301.70 0.18 14,085.82 MWD+IFR-AK-CAZ-SC(5) 19,563.70 93.15 327.57 7,351.16 7,280.23 15,880.56 -600.13 5,981,539.15 1,489,253.14 1.27 14,180.40 MWD+IFR-AK-CAZ-SC(5) 11/24/2015 11:55:09AM Page 7 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-03 Project: Western North Slope TVD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-03:34.1+36.83 @ 70.93usft(Doyon 19) Well: CD5-03 North Reference: True Wellbore: CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 19,659.57 93.21 329.81 7,345.84 7,274.91 15,962.34 -649.87 5,981,621.91 1,489,205.06 2.33 14,276.04 MWD+IFR-AK-CAZ-SC(5) 19,753.65 92.02 329.85 7,341.55 7,270.62 16,043.58 -697.10 5,981,704.08 1,489,159.47 1.27 14,370.00 MWD+IFR-AK-CAZ-SC(5) 19,849.98 91.13 331.05 7,338.90 7,267.97 16,127.35 -744.59 5,981,788.78 1,489,113.68 1.55 14,466.28 MWD+IFR-AK-CAZ-SC(5) 19,945.55 90.13 329.96 7,337.85 7,266.92 16,210.53 -791.64 5,981,872.88 1,489,068.31 1.55 14,561.84 MWD+IFR-AK-CAZ-SC(5) 20,040.96 90.06 330.35 7,337.70 7,266.77 16,293.28 -839.12 5,981,956.57 1,489,022.51 0.42 14,657.24 MWD+IFR-AK-CAZ-SC(5) 20,135.12 90.13 331.41 7,337.54 7,266.61 16,375.54 -884.95 5,982,039.72 1,488,978.35 1.13 14,751.40 MWD+IFR-AK-CAZ-SC(5) 20,231.42 90.10 330.96 7,337.35 7,266.42 16,459.92 -931.36 5,982,125.01 1,488,933.65 0.47 14,847.70 MWD+IFR-AK-CAZ-SC(5) 20,326.61 90.13 332.00 7,337.16 7,266.23 16,543.55 -976.81 5,982,209.53 1,488,889.89 1.09 14,942.88 MWD+IFR-AK-CAZ-SC(5) 20,421.08 90.03 332.62 7,337.02 7,266.09 16,627.20 -1,020.71 5,982,294.04 1,488,847.68 0.66 15,037.33 MWD+IFR-AK-CAZ-SC(5) 20,516.76 90.59 333.38 7,336.51 7,265.58 16,712.45 -1,064.15 5,982,380.14 1,488,805.97 0.99 15,132.95 MWD+IFR-AK-CAZ-SC(5) 20,613.10 90.65 333.89 7,335.46 7,264.53 16,798.77 -1,106.93 5,982,467.29 1,488,764.94 0.53 15,229.18 MWD+IFR-AK-CAZ-SC(5) 20,707.11 90.58 332.93 7,334.45 7,263.52 16,882.83 -1,149.00 5,982,552.18 1,488,724.56 1.02 15,323.10 MWD+IFR-AK-CAZ-SC(5) 20,802.44 90.58 333.31 7,333.49 7,262.56 16,967.85 -1,192.10 5,982,638.04 1,488,683.18 0.40 15,418.36 MWD+IFR-AK-CAZ-SC(5) 20,898.28 90.65 334.48 7,332.46 7,261.53 17,053.91 -1,234.27 5,982,724.92 1,488,642.76 1.22 15,514.07 MWD+IFR-AK-CAZ-SC(5) 20,939.03 90.72 333.72 7,331.97 7,261.04 17,090.56 -1,252.07 5,982,761.93 1,488,625.70 1.87 15,554.76 MWD+IFR-AK-CAZ-SC(5) 20,990.00 90.72 333.72 7,331.33 7,260.40 17,136.26 -1,274.63 5,982,808.06 1,488,604.06 0.00 15,605.67 NOT an Actual Survey 4-1/2"x 6-1/2" 20,999.00 90.72 333.72 7,331.22 7,260.29 17,144.33 -1,278.62 5,982,816.21 1,488,600.24 0.00 15,614.66 PROJECTED to TD 11/24/2015 11:55:09AM Page 8 COMPASS 5000.1 Build 74 \���� //7 4N THE STATE Alaska Oil and Gas — .4, of Conservation Commission ALASKA it _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALA`9�� Fax: 907.276.7542 www.aogcc.alaska.gov Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Colville River Field,Alpine Oil Pool, CRU CD5-03 ConocoPhillips Alaska, Inc. Permit No: 215-146 Surface Location: 305' FNL, 2451' FWL, Sec. 18, Ti 1N, R4E,UM Bottomhole Location: 4296' FNL, 3679' FEL, Sec. 30, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs 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, zijA P rag.th371. Foerster Chair DATED this /1 day of September, 2015. RECEIVED STATE OF ALASKA AlIltA OIL AND GAS CONSERVATION COMIDN AUG 18 2015 PERMIT TO DRILL ���� 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil 0 _ Service- Winj ❑ Single Zone 2 , l c.Specify if well is proposed for: Drill E Lateral ❑ Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket El . Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc.- Bond No. 59-52-180 . CRU CD5-03 ' 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 20999 ' TVD: '7341 Colville River Unit. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number):fka Alpine Pool . Surface: 305'FNL,2451' FWL,Sec. 18,T11 N,R4E,UM ASRC NPR4,ASRC NPR2,AAL287208 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4756'FNL,641'FEL,Sec.31,T12N,R4E,UM 932128,932671,932193 9/15/2015 Total Depth: 9.Acres in Property: fl(I?j 14. Distance to Nearest Property: 4296'FNL,3679'FEL,Sec.30,T12N,R4E,UM i 15912, 12614.53, 9148 a7. 1161 to ADL 388466 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above , 70.4 feet 15.Distance to Nearest Well Open Surface: x- 349501 y- 5965905 Zone- 4 ' GL Elevation above 34.1 feet to Same Pool: 2075' 16.Deviated wells: Kickoff depth: , 350 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 90 degrees Downhole: 3 0 -3+5O Surface: ;6139 • Z 7-33 9 V TI-- 18.Casing Program: Specifications Top - Setting Depth - Bottom - Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 30 36 110 110 10 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2365 36 36 2401 2160 1,049 sx 11.0 ppg G,273 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 14457 36 36 14493 i 7411 Stages:353 sx 15.8 ppgG,Stage2:457 sx 15.8 ppgG 6-1/2" 4-1/2" 12.6 L-80 IBTM 6699 14300 7394 20999 7341 n/a 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch El Seabed Report El Drilling Fluid Program I: 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 4/17/2015 22. I hereby certify that the foregoing is true and correct. Greg Hobbs 263-4749 Contact Email I Greg.S.Hobbs@cop.com Printed Name SAN MVP es) Title Drilling Manager Signature A-6. Qk Phone 265-6120 Date 8/12/2015 Commission Use Only Permit to Drill API Number: Permit Approval f / See cover letter for other Number: a 15-/' i 50-103- 02O (8-0 -'0o Date: "1 (t 1I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales: IV Other: 50P f-e-5-' 'f0 35CO3�5) Samples req'd: Yes❑.., Nog Mud log req'd:Yes❑ No[/ /In n v/a r-Pre. v« ftd t5' ,„,h, Z 5o U P 5'aS measures: Yes Lb No❑ Directional svy req'd:Yes[j No❑ L /V e r7Le{' lA Ci.Is V C CI Spacing exception req'd: Yes❑ No CA/ Inclination-only svy req'd:YesE NoCe ( cr' -o44-C 25. O 35 (/ )(21 `�/� APPROVED BY Approved by: (sR 4 (��[/� 7-''j-s COMMISSIONER THE COMMISSION Date: 9-/7-1) ORJIGi (,�Form 10-401(Revised 10/2012) s t �¢ nths from the date of approval(20 AAC 25.00519)) Attachments in Duplicate ConocoPhillips Alaska,Inc. • • Post Offie Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Telephone 907-276-1215 August 17,2015 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 AUG 18 2015 Re: Application for Permit to Drill CRU CD5-03 AOGCC Dear Sir or Madam: V ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD5 drilling pad with rig Doyon 19. The intended spud date for this well is 11/1/15. However,should federal permitting for the CD5-315 injector to support the recent Kuparuk Producer CD5-313 take more time than anticipated, it would be desired to move the rig onto CD5- 03 by 9/15/15. CRU CD5-03 is planned to be Alpine A sand producer. The 13-1/2"surface hole will TD above the C-30 sand and then 10-3/4" casing will be set. The intermediate section will be drilled with 9-7/8"x 11"underreamer BHA and Managed Pressure Drilling technology.This hole will be subsequently cased with a 7-5/8"casing string to surface and cemented to 500' above the uppermost hydrocarbon bearing interval.The su)face by intermediate casing annulus will then be evaluated for future annular 9 disposal by performing a leak-off test. The 6-1/2"production section will then be horizontally drilled and completed as a Alpine A sand producer. The well will be completed with a 4-1/2"solid liner with frac sleeves across the productive zone and tied back to surface with a 3-1/2"gas- lifted upper completion string. i It is the intention of ConocoPhillips to hydruallically fracture CD5-03 at a later date. J, Please find attached the information required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application For Permit to Drill per 20 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling/collision avoidance information as required by 20 AAC 25.050(b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information,please contact Greg Hobbs at 263-4749 (Greg.S.Hobbs(a ConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD5-03 Well File/Sharon Allsup-Drake ATO 1530 40„, Rob Stinson ATO 1720 Chip Alvord ATO 1570 Greg obbs Mandy Pogany ATO 1766 Drilling Engineer Lanston Chin Kuukpik Corp • Applicefor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 CD5-03 Application for Permit to Drill Document Drilling, !', &Wells ConocoPhdhp. Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005 (c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005 (c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005 (c)(11) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD5-03 APD Page 1 of 15 Printed: 17-Aug-15 . Applifor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005(c)(14) 15. Attachments 10 Attachment 1 Cement Summary 11 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Completion Schematic 15 Attachment 4 Directional Plan 16 CD5-03 APD Page 2 of 15 Printed:17-Aug-15 • Applicefor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 1. Well Name (Requirements of 20 AAC 25.005(9) The well for which this application is submitted will be designated as CRU CD5-03. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for Location at Surface 305' FNL,2451' FWL, Sec. 18,T11N,R4E,UM NAD 1927 RKB Elevation 70.4'AMSL Northings: 5,965,905 Eastings: 349,501 Pad Elevation 34.1'AMSL Top of Productive Horizon(Heel) 4756'FNL,641'FEL, Sec.31,T12N,R4E,UM NAD 1927 Measured Depth, RKB: 14,493' Northings: 5,977,254 Total Vertical Depth, RKB: 7,411' Eastings: 351,522 Total Vertical Depth, SS: 7,340' Total Depth (Toe) 4296'FNL,3679'FEL, Sec.30,T12N,R4E,UM NAD 1927 Measured Depth, RKB: 20,999' Northings: 5,983,054 Total Vertical Depth, RKB: 7,341' Eastings: 348,578 Total Vertical Depth, SS: 7,270' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. CD5-03 APD Page 3 of 15 Printed: 17-Aug-15 • Appli.for Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Size Csg Setting Depth Fracture Pore pressure ASP Drilling (in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 20 110/ 110 10.9 50 51 10.75 2,401/2,160 14.5 977 1,412 7.625 14,493/7,411 12.5 3480 2,518 N/A 20,999/7,341 12.5 3252 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FG x 0.052)-0.1]*D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(0.1 xD) Where: FPP=Formation Pore Pressure at the next casing point FPP=0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20"conductor ASP= [(FG x 0.052)-0.1]D =[(10.9 x 0.052)-0.1]x 110=51 psi OR ASP=FPP-(0.1 x D) =977-(0.1 x 2160')=761 psi 2. Drilling below 10-3/4"surface casing ASP= [(FG x 0.052)-0.1]D =[(14.5 x 0.052)-0.1]x 2160' = 1412 psi OR ASP=FPP-(0.1 x D) = 3480-(0.l x 7411')=2739 psi 3. Drilling below 7-5/8"intermediate casing ASP=[(FG x 0.052)-0.1]D =[(12.5 x 0.052)-0.1]x 7411 =4076 psi OR ASP=FPP-(0.1 x D) =3252-(0.1 x 7341')=2518 psi (B)data on potential gas zones; CD5-03 APD Page 4 of 15 Printed: 17-Aug-15 • Loepp, Victoria T (DOA) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, September 09, 2015 11:17 AM To: Loepp, Victoria T (DOA) Cc: Dai, Weifeng Subject: RE: CD5-03 Drilling Permit Timing; MPSP; Diverter; PTD 215-146 Victoria- Apologies for the error in the maximum surface pressure. I would like to use the 2739 psi as calculated for drilling below the 10 3/4" casing. My reasoning is that this is the highest anticipated pressure penetrated at the heel of the lateral (3480 psi) and is accessed by both the intermediate and production hole sections. The 3252 psi bottom hole pressure estimate used below the 7 5/8" casing is an average of the pressure traverse across the lateral from the reservoir engineer. The 401 should read the maximum downhole pressure of 3480, and surface pressure of 2739. I failed to change these after the calculations. Greg From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Wednesday, September 09, 2015 10:19 AM To: Hobbs, Greg S Subject: [EXTERNAL]RE: CD5-03 Drilling Permit Timing; MPSP; Diverter; PTD 215-146 Greg, r C Please provide a diverter route schematic with 75' radius area indicated at discharge. � � r 6,- ,'�� Please review MPSP: On 401 form is shown as 2659 psig whereas ASP shown in table is 2518 psig. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Vicforia.Loerr@alaska.gov 1 • Applillifor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 The well bore is not expected to penetrate any gas zones. (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing_and Cementin Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) ��) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 80 30/30 110/ 110 Previously Installed HYD Cement to Surface with 10-3/4 13.5 45.5 L-80 563 X 2,385 36/36 2,401/2,160 1049 sx ASLite Lead 11.0 ppg, BTCM 273 sx Class"G"Tail Slurry 15.8 ppg HYD 7-5/8 9'875 29.7 L-80 563 X 14,457 36/36 14,493/7,411 Stage 1: 353 sx Class G at 15.8 ppg x11 BTCM Stage 2: 457 sx Class G at 15.8 ppg 4-1/2 6.5 12.6 L-80 IBT-M 6,699 14,300/7,394 20,999/7,341 N/A—uncemented liner with frac sleeves 3-1/2 6.75 9.3 L-80 EUE 14,264 36/36 14,300/7,394 N/A-production tubing 7. Diverter System Information (Requirements of20AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2)is granted. At CD5, four penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates w ctiAte above the C30 where casing will be set. 1:39t CD5-03 APD Page 5 of 15 Printed: 17-Aug-15 Applic4110for Permit to Drill,Well CRU CD5-03 Saved 17-Aug-15 8. Drilling Fluid Program (Requirements of 20AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.5 Casing Size in. 10.75 7.625 4.5 Density PPG 8.8— 10.0 9.6—11.5 9.1 PV cP 30 - 80 10 10 YP Ib./100ft2 100 - 200 20 - 28 10 - 15 Funnel Viscosity s/qt. 300 50-60 40- 50 Initial Gels Ib./100 ft2 50 10 6 10 Minute Gels Ib./100 ft2 60 15 8 API Fluid Loss cc/30 min. N.C.— 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0— 12.0 10.0 pH 11.0 9.5- 10.0 9.0-9.5 Surface Hole: A mixed-metal oxide fresh water drilling fluid(Drilpiex)will be used for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing.Reduce viscosity prior to cementing.Maintain mud weight< 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate#1: Fresh water gel/polymer mud system.Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids(by diluting as required)will all be important in maintaining wellbore stability.The mud will be weighted up to 11.5 before pulling out of the hole. Note: Managed Pressure Drilling(MPD)will be utilized for added backpressure to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill-in fluid(FloPro)weighted to 9.1 ppg with calcium carbonate and KC1. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-03 APD Page 6 of 15 Printed: 17-Aug-15 • Appliccfor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 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 of20 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 not for an offshore 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)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto CD5-03. 2. Rig up and test riser,dewater cellar as needed. 3. Drill 13.5"hole to the surface casing point as per the directional plan(LWD Program:GR). ✓ 4. Run and cement 10-3/4"surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low/3500 psi high. 7. Pick up and run in hole with 9-7/8"x 11"drilling BHA to drill the intermediate hole section. 8. Pressure test casing to 3500 psi. 9. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.0 ppg.Minimum LOT required to drill ahead is 12.5 ppg EMW. 10. Drill 9-7/8"x 11"hole to section TD using Managed Pressure Drilling to maintain constant bottom hole pressure on connections(LWD Program: GR/Res). 1/ 11. Run 7-5/8"casing and cement to 500' above hydrocarbon bearing zones. 12. Test BOPE to 250 psi low/3,500 psi high. 13. Pick up and run in hole with 6-1/2"drilling BHA.Pressure test casing to 3,500 psi. 14. Drill out shoe track and 20 feet of new formation.Perform LOT to a maximum of 18 ppg.Minimum required leak-off value is 12.0 ppg EMW. / 15. Drill 6-1/2"hole to section TD(LWD Program: GR/Azimuthal Res.). d 16. Pull out of hole with drilling BHA. 17. RIH with 4.5"liner completion(solid liner with frac sleeves)on 4"drill pipe. 18. Set liner top packer and release from liner. 19. Displace well to seawater. 20. Run 3.5"upper completion. 21. Space out and land hanger. CD5-03 APD Page 7 of 15 Printed: 17-Aug-15 Applicfor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 22. Install 2-way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 23. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi.Remove 2-way check. 24. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 25. Shear circulation valve in GLM. 26. Circulate tubing to diesel and install freeze protection in the annulus. 27. Set BPV and secure well.RDMO. CD5-03 APD Page 8 of 15 Printed: 17-Aug-15 • Appliclifor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD5-03 will be injected into the surface casing x production casing annulus of CD5-313 and/or CD5-05 and/or CD5-315 wells upon approval.Well CD1-01A will be used as a backup disposal well or for excess fluid volumes. The CD5-03 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include only the Alpine sand based on pre-drill interpretations. There will be 500' of cement fill placed above the top of the Alpine reservoir. Once CD5-03 has been drilled and completed,consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations,per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above,any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation(C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes.Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection,the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure =(12.0 ppg)*(0.052)*(Surf. Shoe TVD)+ 1,500 psi =(12.0 ppg)*(0.052)*(2,160')+ 1,500 psi =2966 psi Pore Pressure = 1,049 psi Therefore Differential=2966— 1049= 1916 psi. The internal casing pressure is conservative,since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85%collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85%of Burst 85%of (PO Type Collapse Burst 10-3/4" 45.5 L-80 3 HYD563 2470 psi 2100 psi 5210 psi 4429 psi 10-3/4" 45.5 L-80 3 BTC-M 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563 4790 psi 4071 psi 6890 psi 5856 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi CD5-03 APD Page 9 of 15 Printed: 17-Aug-15 • ApplicOfor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-03 APD Page 10 of 15 Printed: 17-Aug-15 411, Applic.for Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 Attachment 1 —Cement Summary CD5-03 Cementing Program: CD5-03_wp08 Sidetrack Schematic 20"94#H-40 Welded Conductor to 115' 10-3/4"45.5#L-80 HYD563/BTCM 2,401' MD/2,160'TVD @ 54° inc. Top of Cement 5,853' MD/3,742'TVD K2(Qannik) 6,353'MD/3,968 TVD Contingent HES Cementer O O 0 6,893' MD/4,213 TVD 9-7/8"x 11" Hole Top of Cement 13,684' MD/7,255'TVD Alpine C 7-5/8"29.7#L-80 HYD563 X BTCM Casing 14,184' MD/7,377 TVD16. 14,493' MD/7,411'TVD @ 87° 6-1/2" Hole 4-1/2"Solid Liner 12.6 ppf L80 IBTM 20,999'.MD/7,340 @ 91° CD5-03 APD Page 11 of 15 Printed: 17-Aug-15 • Applicelfor Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 10.75" Surface Casing run to 2,401' MD/2,160' TVD Cement from 2401' MD to 1901'(500' of tail)with Class G+Adds. @ 15.8 PPG,and from 1901'to surface with 11.0 ppg Arctic Lite Crete. Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1343' MD), zero excess in 20"conductor. Lead slurry from 1,901' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (110'—0') X 1.3645 ft3/ft X 1.0 (0%excess) = 150 ft3 Permafrost to Conductor (1,343'— 110') X 0.3637 ft3/ft X 3.5 (250% excess) = 1,570 ft3 Top of Tail to Permafrost (1,901'— 1,343')X 0.3637 ft3/ft X 1.5 (50%excess) = 305 ft3 Total Volume = 150 + 1,889 + 224 = 2,024 ft3=> 1,049 sx of 11.0 ppg Arctic Lite Crete @ 1.93 ft3 /sk Tail slurry from 2,401'MD to 1,901'MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,401'—1,901')X 0.3637 ft3/ft X 1.50 (50%excess) = 273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 273 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.80/0 S002 accelerator @ 1.16 ft3/sk 7.625"Intermediate Casing run to 14,493' MD/7,411' TVD Top of slurry is designed to be at 13,684' MD, which is 500' above the Alpine C.Assume 40%excess annular volume. Tail slurry from 14,493' MD to 13,684'MD with 15.8 ppg Class G + additives Shoe to Top of Cement (14,493'— 13,684')X 0.3428 ft3/ft X 1.40 (40%excess) = 388 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) = 21 ft3 Total Volume = 280 + 21 = 409 ft3 => 353 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk Qannik Second Stage from 6893-5853 MD with 15.8 ppg Class G + additives 1,040'MD Across Qannik (6,893'—5,853')X 0.3637 ft3/ft X 1.40 (40%excess) = 530 ft3 Total Volume = 530 ft3 => 457 sx of 15.8 ppg Class G + 0.2% D046 antifoamer,0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk CD5-03 APD Page 12 of 15 Printed. 17-Aug-15 Appli for Permit to Drill,Well CRU CD5-03 Saved. 17-Aug-15 Attachment 2— Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots,traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight,decreased Gas Hydrates Low mud viscosity,increased circulating times,controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters,Increase mud weight,use weighted sweeps. Lost Circulation Low Reduced pump rates,mud rheology,lost circulation material,use of low density cement slurries 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers 6-1/2"/4-1/2"Liner Production Interval Event _ Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers CD5-03 APD Page 13 of 15 Printed: 17-Aug-15 • Applic.for Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability:HRZ/Kalubik and instability in the production interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. CD5-03 APD Page 14 of 15 Printed: 17-Aug-15 • Appli for Permit to Drill,Well CRU CD5-03 Saved: 17-Aug-15 Attachment 3— Completion Schematic CD5 -03 Alpine A Producer Wp07 Proposed Schematic updated 8/14/2015 by G. Hobbs " ''i 20"94#H-40 Welded Upper Completion: Length €!k Conductor to 114' 1)4-1/2" 12.6#/ft IBT-M Tubing(2 jts) XO to 3-1/2"EUE tubing 2)Shallow nipple profile 3)3-1/2"x 1"Camco KBMG GLM (xx°)w/DV 7' 4)3-1/2"x 1"Camco KBMG GLM(xx°)w/DV 7' J 10-3/4"45.5#L-80 Hyd 563/ 4)3-W x 1"Camco KBMG GLM(xx°)w/DCK2 7' iiiil: BTC pinned for 2500 psi casing to tbg shear Surface Casing 5)SLB BHP Gauge, Encapsulated I-Wire 1.5' 2,401'MD/2,160'TVD @ 54' w/cannon clamps on every joint cemented to surface 6)Baker Premier Packer 7)X nipple 2.812"ID 1.5' 8)WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5"Hydril 521 Box X 4-1/2" IBTM pin 10)4'/2", 12.6#/ft, L-80 IBT-M Liner w/ball actuated frac ports every-750' 3-1/2" 9.3#L-80 EUE 14,300'MD • Baker Premier Production Packer Top Reservoir at+/- Alpine A Sand 7407'TVD _ O o O O o o o o o O 6 1/2"Hole TD 4-1/2"12.6#L-80 Liner 20,999'MD/7,340'TVD 7 5/8" Intermediate shoe 14,492' MD / 7410' TVD @ 87° CD5-03 APD Page 15 of 15 Printed: 17-Aug-15 il • DDJ. CD5-03wp08 7 . 014 Plan Summary - LCU Alpine C UJU >.5_ Kuparuk C ' Alpine A 5 Ease Permafrost `,' 1 /_ Kalubik ' 1 HRZ_ x"414 U) �- Albian 97 -- o - r c-30 K-n(Qann Alban 9E 75/8"x9-7/81 �.� '11111,111111101111rr o , - i K-3 y i I 0 • II i 1 r ( I I I 1 1 11 1 0 141‘ 10-3/4"x 13-1/2 \\\11.,0 '5000 10000 15000 200001 i1r MeasuDepth I3-1/2"x 6-3/4 /,0-_0° Geodetic Datum: North American Datum 1983 , I10-3/4"x 13-1/21 Depth Reference: Plan:34.1+36.3 @ 70.a0usft(Doyon 19) `�;��Oo_o Rig: Doyon 19o p o-0 Xa 0�, 00 At\i100*.111r co o X00 000 0 7515"x sa/e 13-1/2"x 6-3/41 0o 0 00 0� 19 0 ° ° / 1 1 1 1 1 1 1 1 I I I I I I �1 N� 1 O -�" I "M- /' 1 I 0 2000 4000 6000 8000 10000 123008 1 700° 1x60000 18000 0 36 '- 350 Departure 350 - 540 Horizontal De P 330 MIN, Sao - 740 740 - 930 I930 - 1120 caj/ D506wP07 .,.CDS-99wp08 1 1120 - 1320 m 60 60 1320 - 1510 O. 15135 --D5wp10 1510 - noo y� p . _ ��� z,.om 1700 25001t ,. -030 . + ' ,r -‘.fI ; ICm '- :_I cosu,..po74900 - 5700 ` f - ` `l 5700 - 6500 4lirr CJ - - _ .-419,,,4 6500 - 7300 0 Iii 1 i I Milli I I I I I I I III I I I I I .411•204, 7300 - 8100 I � 8100 - 9710 0 3000 6000 9000 12000 15000 18000 21000 240 � 1120 9710 - 11320 i'`�... 1r" - 11320 - 12940 SURVEY PROGRAM • ; ' ,;ar�i Icor-ssgoel Surface Location " :4r/� a ri, 12940 - 14550 ,epth From Depth To Survey/Plan Tool Pad Elevation:34.10 '.5:-,',f,';'!./.4'0,0 14550 - 16160 36.30 800.00 CD5-03wp08(Plan CD5-03) GYD-GC-SSIco5. m1-210 pI150 800.00 1800.00 CD5-03wp08(Plan CD5-03) MWD iii fl `'�r. cosos ro 16160 17770 I800.00 2400.71 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC 180 cos o. W° 17770 1939d 2400.71 3900.71 CD5-03wp08(Plan CD5-03) MWD CASING DETAILS Icoson,Pm I 19390 - 20998 2400.71 14492.56 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC TVD MD Name 14492.56 15992.56 CD5-03wp08(Plan CD5-03) MWD 2159.40 2400.71 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 14492.56 20998.38 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC 7410.40 14492.56 7-5/8"x 9-7/8" Magnetic Model Date: 06-Nov-15 7340.40 20998.38 3-1/2"x 6-3/4" Magnetic Declination: 17.93° - To convert a Magnetic Direction to a True Direction,Add 17.93°East SECTION DETAILS - 1320.4 Sec MD Inc Azi ND +W-S +EJ-W Dleg TFace VSect Target Annotation 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 Base Permafrost 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,340°TF,for 250.18' 3 600.18 3.75 340.00 600.00 7.70 -2.80 1.50 340.00 8.09 Start 2.51100'DLS,10°TF,for 688.8' 4 1288.98 20.93 348.28 1270.40 150.39 -35.75 2.50 10.00 148.87 Hold for 107.06' -2320.4 5 1396.04 20.93 348.28 1370.40 187.83 -43.52 0.00 0.00 185.38 Start 3.5°1100'DLS,30.85°TF,for 1004.67' 6 2400.71 54.06 9.67 2159.40 783.21 -10.63 3.50 30.85 690.16 Hold for 20' 7 2420.71 54.06 9.67 2171.14 799.17 -7.91 0.00 0.00 702.80 Start 3.51100'DLS,13.07°TF,for 264.69' 8 2685.40 63.10 12.01 2309.00 1020.71 34.74 3.50 13.07 875.90 Hold for 10516.83' 9 13202.22 63.10 12.01 7066.78 10194.52 1986.25 0.00 0.00 7953.38 Start 3.5°/100'DLS,-65.06°TF,for 1290.34' C-30 10 14492.56 87.00 331.93 7410.40 11388.25 1792.66 3.50 -65.06 9091.29 CD5-03 01 Heel 062515 DK Hold for 20' 11 14512.56 87.00 331.93 7411.45 11405.87 1783.26 0.00 0.00 9111.26 Start 31100'DLS,0°TF,for 122.07' 12 14634.63 90.66 331.93 7413.94 11513.54 1725.84 3.00 0.00 9233.26 Hold for 6363.76' 13 20998.38 90.66 331.93 7340.40 17128.32 -1268.53 0.00 0.0015595.76 CD5-03 02.Toe 062515 DK TD:20998.38'MD,7340.4'ND -371Kg.g4 -3968.4 Updated surface location from as-built. Changed RKB. New formation tops. Changed K-2(Oannik) -4330.4 doglegs through permafrost and in intermediate section. 8/17/15: Changed gyro depth Albian 97 to 800' MD from 1150' MD. -5276.4 REVISED Alban 96 12:12 pm, Aug 17, 2015 ZZ22 J 4, IneC ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie Weifeng Dai et 0-4K ac n 4 ,,, < co__ , ca- in co cy, .„,_ ire .• T-(3!r .----,-.- cy) 'zi- , 0_ -,- " al- ,%to C1,1• N ,- -,'-'- .1-ct co 4 a) co 4. aica Cil -tt-. asai-Ja gAv ' "1"-g (0® usftotne co cr) ," cm c\I 0 c? CU ..,•.' 4 .1.1.., Cii CM 7v.. a_ qy--• • ,7.41 i i.--1,'"' •is 1 en 7 * ,_ f._ 010 - • •.-- CD r_j.9",51 co cr.) .1. 4 o %.,.... 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N •— T CM � '_ ! 0000 CDi LO N O ' 40▪ 1. i CD ffO00O O —T , , i O 4O0 , O O o — C'7 I/\ T 10 N CO T ai C Q U Cl.) ?000 O T V T i Q Uc Q , Ii in ap • • X000 CDLO O • \ \ \• \ OO61 V/ \ ,\ ,, , I \ 000 I co v \\\ Ln Cp , 00 , , I I I O O co co O co N O OD CO 7r N r N N CO d- LU q daa leawaA ar� nal • • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-03 Plan CD5-03 Plan: CD5-03wp08 Report - Basic 17 August, 2015 • Schlumberger • Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Well Plan:CD5-03 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 34.10 usft Wellbore Plan CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/6/2015 17.93 80.83 57,471 Design CD5-03wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 'Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.30 0.00 0.00 331.00 Survey Tool Program Date 8/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 36.30 800.00 CD5-03wp08(Plan CD5-03) GYD-GC-SS Gyrodata gyro single shots 800.00 1,800.00 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 800.00 2,400.71 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,400.71 3,900.71 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 2,400.71 14,492.56 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,492.56 15,992.56 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 14,492.56 20,998.38 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey Multiply by 2.58 MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 36.30 0.00 0.00 36.30 -34.10 0.00 0.00 0.00 100.00 0.00 0.00 100.00 29.60 0.00 0.00 0.05 200.00 0.00 0.00 200.00 129.60 0.00 0.00 0.19 300.00 0.00 0.00 300.00 229.60 0.00 0.00 0.34 350.00 0.00 0.00 350.00 279.60 0.00 0.00 0.41 KOP:Start 1.5°l100'DLS,340°TF,for 250.18' 400.00 0.75 340.00 400.00 329.60 1.50 340.00 0.48 8/17/2015 11:53:32AM Page 2 COMPASS 5000.1 Build 74 SSchlumberger S Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.4ousft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.4ousft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 500.00 2.25 340.00 499.96 429.56 1.50 0.00 0.62 600.00 3.75 340.00 599.82 529.42 1.50 0.00 0.77 600.18 3.75 340.00 600.00 529.60 1.50 0.00 0.77 Start 2.5°/100'DLS,10°TF,for 688.8' 700.00 6.23 344.00 699.44 629.04 2.50 10.00 0.91 800.00 8.72 345.73 798.58 728.18 2.50 6.02 1.07 900.00 11.21 346.69 897.06 826.66 2.50 4.30 1.16 1,000.00 13.71 347.31 994.70 924.30 2.50 3.35 1.25 1,100.00 16.20 347.74 1,091.31 1,020.91 2.50 2.75 1.44 1,200.00 18.70 348.05 1,186.69 1,116.29 2.50 2.33 1.75 1,288.98 20.93 348.28 1,270.40 1,200.00 2.50 2.03 2.12 Hold for 107.06' 1,300.00 20.93 348.28 1,280.70 1,210.30 0.00 0.00 2.17 1,342.51 20.93 348.28 1,320.40 1,250.00 0.00 0.00 2.62 Base Permafrost 1,396.04 20.93 348.28 1,370.40 1,300.00 0.00 0.00 2.62 Start 3.5°/100'DLS,30.85°TF,for 1004.67' 1,400.00 21.04 348.47 1,374.10 1,303.70 3.50 30.85 2.64 1,500.00 24.12 352.84 1,466.43 1,396.03 3.50 30.67 3.14 1,600.00 27.29 356.27 1,556.53 1,486.13 3.50 26.63 3.72 1,700.00 30.53 359.02 1,644.06 1,573.66 3.50 23.54 4.37 1,800.00 33.81 1.28 1,728.70 1,658.30 3.50 21.13 5.11 1,900.00 37.13 3.19 1,810.12 1,739.72 3.50 19.21 2.62 2,000.00 40.48 4.83 1,888.04 1,817.64 3.50 17.66 2.93 2,100.00 43.85 6.25 1,962.15 1,891.75 3.50 16.39 3.28 2,200.00 47.23 7.51 2,032.19 1,961.79 3.50 15.33 3.65 2,300.00 50.63 8.64 2,097.88 2,027.48 3.50 14.45 4.04 2,400.00 54.03 9.66 2,158.98 2,088.58 3.50 13.70 4.46 2,400.71 54.06 9.67 2,159.40 2,089.00 3.50 13.08 4.46 Hold for 20'-10-314"x 13-1/2" 2,420.71 54.06 9.67 2,171.14 2,100.74 0.00 11.33 4.56 Start 3.5°/100'DLS,13.07°TF,for 264.69' 2,500.00 56.76 10.42 2,216.15 2,145.75 3.50 13.07 5.06 2,600.00 60.18 11.30 2,268.44 2,198.04 3.50 12.64 5.88 2,685.40 63.10 12.01 2,309.00 2,238.60 3.50 12.18 6.72 Hold for 10516.83' 2,700.00 63.10 12.01 2,315.61 2,245.21 0.00 0.00 6.88 2,710.60 63.10 12.01 2,320.40 2,250.00 0.00 0.00 7.97 C-30 2,800.00 63.10 12.01 2,360.85 2,290.45 0.00 0.00 7.97 2,900.00 63.10 12.01 2,406.09 2,335.69 0.00 0.00 9.12 3,000.00 63.10 12.01 2,451.32 2,380.92 0.00 0.00 10.30 3,100.00 63.10 12.01 2,496.56 2,426.16 0.00 0.00 11.52 3,200.00 63.10 12.01 2,541.80 2,471.40 0.00 0.00 12.75 3,300.00 63.10 12.01 2,587.04 2,516.64 0.00 0.00 14.00 8/17/2015 11:53:32AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 3,400.00 63.10 12.01 2,632.28 2,561.88 0.00 0.00 15.25 3,500.00 63.10 12.01 2,677.52 2,607.12 0.00 0.00 16.52 3,600.00 63.10 12.01 2,722.76 2,652.36 0.00 0.00 17.79 3,700.00 63.10 12.01 2,768.00 2,697.60 0.00 0.00 19.07 3,800.00 63.10 12.01 2,813.24 2,742.84 0.00 0.00 20.35 3,900.00 63.10 12.01 2,858.48 2,788.08 0.00 0.00 21.63 4,000.00 63.10 12.01 2,903.72 2,833.32 0.00 0.00 10.40 4,100.00 63.10 12.01 2,948.96 2,878.56 0.00 0.00 10.87 4,200.00 63.10 12.01 2,994.20 2,923.80 0.00 0.00 11.34 4,300.00 63.10 12.01 3,039.44 2,969.04 0.00 0.00 11.82 4,400.00 63.10 12.01 3,084.68 3,014.28 0.00 0.00 12.30 4,500.00 63.10 12.01 3,129.92 3,059.52 0.00 0.00 12.78 4,600.00 63.10 12.01 3,175.16 3,104.76 0.00 0.00 13.26 4,700.00 63.10 12.01 3,220.40 3,150.00 0.00 0.00 13.74 4,800.00 63.10 12.01 3,265.64 3,195.24 0.00 0.00 14.23 4,900.00 63.10 12.01 3,310.88 3,240.48 0.00 0.00 14.72 5,000.00 63.10 12.01 3,356.12 3,285.72 0.00 0.00 15.21 5,100.00 63.10 12.01 3,401.36 3,330.96 0.00 0.00 15.70 5,200.00 63.10 12.01 3,446.60 3,376.20 0.00 0.00 16.19 5,300.00 63.10 12.01 3,491.84 3,421.44 0.00 0.00 16.68 5,400.00 63.10 12.01 3,537.08 3,466.68 0.00 0.00 17.18 5,500.00 63.10 12.01 3,582.32 3,511.92 0.00 0.00 17.67 5,600.00 63.10 12.01 3,627.56 3,557.16 0.00 0.00 18.17 5,700.00 63.10 12.01 3,672.80 3,602.40 0.00 0.00 18.66 5,800.00 63.10 12.01 3,718.04 3,647.64 0.00 0.00 19.16 5,867.11 63.10 12.01 3,748.40 3,678.00 0.00 0.00 19.66 K-3 5,900.00 63.10 12.01 3,763.28 3,692.88 0.00 0.00 19.66 6,000.00 63.10 12.01 3,808.52 3,738.12 0.00 0.00 20.16 6,100.00 63.10 12.01 3,853.76 3,783.36 0.00 0.00 20.66 6,200.00 63.10 12.01 3,899.00 3,828.60 0.00 0.00 21.16 6,300.00 63.10 12.01 3,944.24 3,873.84 0.00 0.00 21.66 6,353.41 63.10 12.01 3,968.40 3,898.00 0.00 0.00 22.16 K-2(Qannik) 6,400.00 63.10 12.01 3,989.48 3,919.08 0.00 0.00 22.16 6,500.00 63.10 12.01 4,034.72 3,964.32 0.00 0.00 22.66 6,600.00 63.10 12.01 4,079.96 4,009.56 0.00 0.00 23.16 6,700.00 63.10 12.01 4,125.20 4,054.80 0.00 0.00 23.66 6,800.00 63.10 12.01 4,170.44 4,100.04 0.00 0.00 24.16 6,900.00 63.10 12.01 4,215.68 4,145.28 0.00 0.00 24.67 7,000.00 63.10 12.01 4,260.91 4,190,51 0.00 0.00 25.17 7,100.00 63.10 12.01 4,306.15 4,235.75 0.00 0.00 25.67 7,153.59 63.10 12.01 4,330.40 4,260.00 0.00 0.00 26.18 Albian 97 7,200.00 63.10 12.01 4,351.39 4,280.99 0.00 0.00 26.18 8/17/2015 11:53:32AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger 0 Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 7,300.00 63.10 12.01 4,396.63 4,326.23 0.00 0.00 26.68 7,400.00 63.10 12.01 4,441.87 4,371.47 0.00 0.00 27.18 7,500.00 63.10 12.01 4,487.11 4,416.71 0.00 0.00 27.69 7,600.00 63.10 12.01 4,532.35 4,461.95 0.00 0.00 28.19 7,700.00 63.10 12.01 4,577.59 4,507.19 0.00 0.00 28.70 7,800.00 63.10 12.01 4,622.83 4,552.43 0.00 0.00 29.20 7,900.00 63.10 12.01 4,668.07 4,597.67 0.00 0.00 29.71 8,000.00 63.10 12.01 4,713.31 4,642.91 0.00 0.00 30.21 8,100.00 63.10 12.01 4,758.55 4,688.15 0.00 0.00 30.72 8,200.00 63.10 12.01 4,803.79 4,733.39 0.00 0.00 31.22 8,300.00 63.10 12.01 4,849.03 4,778.63 0.00 0.00 31.73 8,400.00 63.10 12.01 4,894.27 4,823.87 0.00 0.00 32.24 8,500.00 63.10 12.01 4,939.51 4,869.11 0.00 0.00 32.74 8,600.00 63.10 12.01 4,984.75 4,914.35 0.00 0.00 33.25 8,700.00 63.10 12.01 5,029.99 4,959.59 0.00 0.00 33.75 8,800.00 63.10 12.01 5,075.23 5,004.83 0.00 0.00 34.26 8,900.00 63.10 12.01 5,120.47 5,050.07 0.00 0.00 34.77 9,000.00 63.10 12.01 5,165.71 5,095.31 0.00 0.00 35.27 9,100.00 63.10 12.01 5,210.95 5,140.55 0.00 0.00 35.78 9,200.00 63.10 12.01 5,256.19 5,185.79 0.00 0.00 36.29 9,244.67 63.10 12.01 5,276.40 5,206.00 0.00 0.00 36.79 Albian 96 9,300.00 63.10 12.01 5,301.43 5,231.03 0.00 0.00 36.79 9,400.00 63.10 12.01 5,346.67 5,276.27 0.00 0.00 37.30 9,500.00 63.10 12.01 5,391.91 5,321.51 0.00 0.00 37.81 9,600.00 63.10 12.01 5,437.15 5,366.75 0.00 0.00 38.31 9,700.00 63.10 12.01 5,482.39 5,411.99 0.00 0.00 38.82 9,800.00 63.10 12.01 5,527.63 5,457.23 0.00 0.00 39.33 9,900.00 63.10 12.01 5,572.87 5,502.47 0.00 0.00 39.84 10,000.00 63.10 12.01 5,618.11 5,547.71 0.00 0.00 40.34 10,100.00 63.10 12.01 5,663.35 5,592.95 0.00 0.00 40.85 10,200.00 63.10 12.01 5,708.59 5,638.19 0.00 0.00 41.36 10,300.00 63.10 12.01 5,753.83 5,683.43 0.00 0.00 41.87 10,400.00 63.10 12.01 5,799.07 5,728.67 0.00 0.00 42.37 10,500.00 63.10 12.01 5,844.31 5,773.91 0.00 0.00 42.88 10,600.00 63.10 12.01 5,889.55 5,819.15 0.00 0.00 43.39 10,700.00 63.10 12.01 5,934.79 5,864.39 0.00 0.00 43.90 10,800.00 63.10 12.01 5,980.03 5,909.63 0.00 0.00 44.41 10,900.00 63.10 12.01 6,025.27 5,954.87 0.00 0.00 44.91 11,000.00 63.10 12.01 6,070.50 6,000.10 0.00 0.00 45.42 11,100.00 63.10 12.01 6,115.74 6,045.34 0.00 0.00 45.93 11,200.00 63.10 12.01 6,160.98 6,090.58 0.00 0.00 46.44 11,300.00 63.10 12.01 6,206.22 6,135.82 0.00 0.00 46.95 11,400.00 63.10 12.01 6,251.46 6,181.06 0.00 0.00 47.46 11,500.00 63.10 12.01 6,296.70 6,226.30 0.00 0.00 47.96 8/17/2015 11:53:32AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey 1 MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,600.00 63.10 12.01 6,341.94 6,271.54 0.00 0.00 48.47 11,700.00 63.10 12.01 6,387.18 6,316.78 0.00 0.00 48.98 11,800.00 63.10 12.01 6,432.42 6,362.02 0.00 0.00 49.49 11,900.00 63.10 12.01 6,477.66 6,407.26 0.00 0.00 50.00 12,000.00 63.10 12.01 6,522.90 6,452.50 0.00 0.00 50.51 12,100.00 63.10 12.01 6,568.14 6,497.74 0.00 0.00 51.01 12,200.00 63.10 12.01 6,613.38 6,542.98 0.00 0.00 51.52 12,300.00 63.10 12.01 6,658.62 6,588.22 0.00 0.00 52.03 12,400.00 63.10 12.01 6,703.86 6,633.46 0.00 0.00 52.54 12,500.00 63.10 12.01 6,749.10 6,678.70 0.00 0.00 53.05 12,600.00 63.10 12.01 6,794.34 6,723.94 0.00 0.00 53.56 12,700.00 63.10 12.01 6,839.58 6,769.18 0.00 0.00 54.07 12,800.00 63.10 12.01 6,884.82 6,814.42 0.00 0.00 54.58 12,900.00 63.10 12.01 6,930.06 6,859.66 0.00 0.00 55.08 13,000.00 63.10 12.01 6,975.30 6,904.90 0.00 0.00 55.59 13,100.00 63.10 12.01 7,020.54 6,950.14 0.00 0.00 56.10 13,200.00 63.10 12.01 7,065.78 6,995.38 0.00 0.00 56.61 13,202.22 63.10 12.01 7,066.78 6,996.38 0.00 0.00 56.62 Start 3.5°1100'DLS,-65.06°TF,for 1290.34' 13,291.87 64.46 8.86 7,106.40 7,036.00 3.50 -65.06 56.97 HRZ 13,300.00 64.59 8.57 7,109.90 7,039.50 3.50 -63.67 56.97 13,397.14 66.14 5.25 7,150.40 7,080.00 3.50 -63.55 57.06 Kalubik 13,400.00 66.19 5.15 7,151.55 7,081.15 3.50 -62.16 57.06 13,500.00 67.86 1.81 7,190.60 7,120.20 3.50 -62.12 56.97 13,600.00 69.60 358.55 7,226.89 7,156.49 3.50 -60.81 56.72 13,700.00 71.39 355.36 7,260.28 7,189.88 3.50 -59.63 56.33 13,800.00 73.24 352.24 7,290.66 7,220.26 3.50 -58.57 55.80 13,809.56 73.42 351.95 7,293.40 7,223.00 3.50 -57.62 55.14 Kuparuk C 13,816.59 73.56 351.73 7,295.40 7,225.00 3.50 -57.54 55.14 LCU 13,900.00 75.14 349.19 7,317.90 7,247.50 3.50 -57.47 55.14 14,000.00 77.08 346.18 7,341.92 7,271.52 3.50 -56.79 54.37 14,100.00 79.05 343.23 7,362.60 7,292.20 3.50 -56.07 53.48 14,184.26 80.73 340.77 7,377.40 7,307.00 3.50 -55.45 52.48 Alpine C 14,200.00 81.04 340.31 7,379.89 7,309.49 3.50 -55.02 52.48 14,203.27 81.11 340.21 7,380.40 7,310.00 3.50 -54.95 51.39 UJU 14,300.00 83.07 337.42 7,393.72 7,323.32 3.50 -54.93 51.39 14,400,00 85.10 334.56 7,404.03 7,333.63 3.50 -54.55 50.18 14,443.47 85.99 333.32 7,407.40 7,337.00 3.50 -54.25 48.98 Alpine A 8/17/2015 11:53:32AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger S Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 r Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 14,492.56 87.00 331.93 7,410.40 7,340.00 3.50 -54.16 48.98 Hold for 20'-7-5/8"x 9-7/8" 14,500.00 87.00 331.93 7,410.79 7,340.39 0.00 0.00 49.03 14,512.56 87.00 331.93 7,411.45 7,341.05 0.00 0.00 49.12 Start 3°/100'DLS,0°TF,for 122.07' 14,600.00 89.62 331.93 7,414.02 7,343.62 3.00 0.00 49.76 14,634.63 90.66 331.93 7,413.94 7,343.54 3.00 0.00 50.03 Hold for 6363.76' 14,700.00 90.66 331.93 7,413.18 7,342.78 0.00 -48.02 50.54 14,800.00 90.66 331.93 7,412.03 7,341.63 0.00 0.00 51.36 14,900.00 90.66 331.93 7,410.87 7,340.47 0.00 0.00 52.21 15,000.00 90.66 331.93 7,409.71 7,339.31 0.00 0.00 53.09 15,100.00 90.66 331.93 7,408.56 7,338.16 0.00 0.00 54.01 15,200.00 90.66 331.93 7,407.40 7,337.00 0.00 0.00 54.96 15,300.00 90.66 331.93 7,406.25 7,335.85 0.00 0.00 55.94 15,400.00 90.66 331.93 7,405.09 7,334.69 0.00 0.00 56.95 15,500.00 90.66 331.93 7,403.94 7,333.54 0.00 0.00 57.99 15,600.00 90.66 331.93 7,402.78 7,332.38 0.00 0.00 59.05 15,700.00 90.66 331.93 7,401.63 7,331.23 0.00 0.00 60.13 15,800.00 90.66 331.93 7,400.47 7,330.07 0.00 0.00 61.23 15,900.00 90.66 331.93 7,399.31 7,328.91 0.00 0.00 62.36 16,000.00 90.66 331.93 7,398.16 7,327.76 0.00 0.00 52.79 16,100.00 90.66 331.93 7,397.00 7,326.60 0.00 0.00 53.09 16,200.00 90.66 331.93 7,395.85 7,325.45 0.00 0.00 53.38 16,300.00 90.66 331.93 7,394.69 7,324.29 0.00 0.00 53.69 16,400.00 90.66 331.93 7,393.54 7,323.14 0.00 0.00 53.99 16,500.00 90.66 331.93 7,392.38 7,321.98 0.00 0.00 54.30 16,600.00 90.66 331.93 7,391.23 7,320.83 0.00 0.00 54.62 16,700.00 90.66 331.93 7,390.07 7,319.67 0.00 0.00 54.94 16,800.00 90.66 331.93 7,388.91 7,318.51 0.00 0.00 55.27 16,900.00 90.66 331.93 7,387.76 7,317.36 0.00 0.00 55.59 17,000.00 90.66 331.93 7,386.60 7,316.20 0.00 0.00 55.93 17,100.00 90.66 331.93 7,385.45 7,315.05 0.00 0.00 56.26 17,200.00 90.66 331.93 7,384.29 7,313.89 0.00 0.00 56.60 17,300.00 90.66 331.93 7,383.14 7,312.74 0.00 0.00 56.95 17,400.00 90.66 331.93 7,381.98 7,311.58 0.00 0.00 57.30 17,500.00 90.66 331.93 7,380.83 7,310.43 0.00 0.00 57.65 17,600.00 90.66 331.93 7,379.67 7,309.27 0.00 0.00 58.00 17,700.00 90.66 331.93 7,378.51 7,308.11 0.00 0.00 58.36 17,800.00 90.66 331.93 7,377.36 7,306.96 0.00 0.00 58.73 17,900.00 90.66 331.93 7,376.20 7,305.80 0.00 0.00 59.09 18,000.00 90.66 331.93 7,375.05 7,304.65 0.00 0.00 59.46 18,100.00 90.66 331.93 7,373.89 7,303.49 0.00 0.00 59.84 18,200.00 90.66 331.93 7,372.74 7,302.34 0.00 0.00 60.21 18,300.00 90.66 331.93 7,371.58 7,301.18 0.00 0.00 60.59 8/17/2015 11:53:32AM Page 7 COMPASS 5000.1 Build 74 SSchlumberger el Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.4ousft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 18,400.00 90.66 331.93 7,370.43 7,300.03 0.00 0.00 60.97 18,500.00 90.66 331.93 7,369.27 7,298.87 0.00 0.00 61.36 18,600.00 90.66 331.93 7,368.11 7,297.71 0.00 0.00 61.75 18,700.00 90.66 331.93 7,366.96 7,296.56 0.00 0.00 62.14 18,800.00 90.66 331.93 7,365.80 7,295.40 0.00 0.00 62.54 18,900.00 90.66 331.93 7,364.65 7,294.25 0.00 0.00 62.93 19,000.00 90.66 331.93 7,363.49 7,293.09 0.00 0.00 63.33 19,100.00 90.66 331.93 7,362.34 7,291.94 0.00 0.00 63.74 19,200.00 90.66 331.93 7,361.18 7,290.78 0.00 0.00 64.14 19,300.00 90.66 331.93 7,360.03 7,289.63 0.00 0.00 64.55 19,400.00 90.66 331.93 7,358.87 7,288.47 0.00 0.00 64.96 19,500.00 90.66 331.93 7,357.71 7,287.31 0.00 0.00 65.38 19,600.00 90.66 331.93 7,356.56 7,286.16 0.00 0.00 65.79 19,700.00 90.66 331.93 7,355.40 7,285.00 0.00 0.00 66.21 19,800.00 90.66 331.93 7,354.25 7,283.85 0.00 0.00 66.63 19,900.00 90.66 331.93 7,353.09 7,282.69 0.00 0.00 67.06 20,000.00 90.66 331.93 7,351.94 7,281.54 0.00 0.00 67.48 20,100.00 90.66 331.93 7,350.78 7,280.38 0.00 0.00 67.91 20,200.00 90.66 331.93 7,349.63 7,279.23 0.00 0.00 68.34 20,300.00 90.66 331.93 7,348.47 7,278.07 0.00 0.00 68.77 20,400.00 90.66 331.93 7,347.31 7,276.91 0.00 0.00 69.21 20,500.00 90.66 331.93 7,346.16 7,275.76 0.00 0.00 69.64 20,600.00 90.66 331.93 7,345.00 7,274.60 0.00 0.00 70.08 20,700.00 90.66 331.93 7,343.85 7,273.45 0.00 0.00 70.52 20,800.00 90.66 331.93 7,342.69 7,272.29 0.00 0.00 70.97 20,900.00 90.66 331.93 7,341.54 7,271.14 0.00 0.00 71.41 20,998.38 90.66 331.93 7,340.40 7,270.00 0.00 0.00 71.85 TD:20998.38'MD,7340.4'TVD-3-1/2"x 6-3/4" 8/17/2015 11:53:32AM Page 8 COMPASS 5000.1 Build 74 • Schlumberger • Report-Basic Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 20,998.38 7,340.40 3-1/2"x 6-3/4" 3-1/2 6-3/4 14,492.56 7,410.40 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,400.71 2,159.40 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (`) 6,353.41 3,968.40 K-2(Qannik) 14,184.26 7,377.40 Alpine C 9,244.67 5,276.40 Albian 96 13,397.14 7,150.40 Kalubik 13,291.87 7,106.40 HRZ 1,342.51 1,320.40 Base Permafrost 7,153.59 4,330.40 Albian 97 13,809.56 7,293.40 Kuparuk C 2,710.60 2,320.40 C-30 13,816.59 7,295.40 LCU 5,867.11 3,748.40 K-3 14,443.47 7,407.40 Alpine A 14,203.27 7,380.40 UJU I Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,340°TF,for 250.18' 600.18 600.00 7.70 -2.80 Start 2.5°/100'DLS,10°TF,for 688.8' 1,288.98 1,270.40 150.39 -35.75 Hold for 107.06' 1,396.04 1,370.40 187.83 -43.52 Start 3.5°/100'DLS,30.85°TF,for 1004.67' 2,400.71 2,159.40 783.21 -10.63 Hold for 20' 2,420.71 2,171.14 799.17 -7.91 Start 3.5°/100'DLS,13.07°TF,for 264.69' 2,685.40 2,309.00 1,020.71 34.74 Hold for 10516.83' 13,202.22 7,066.78 10,194.52 1,986.25 Start 3.5°/100'DLS,-65.06°TF,for 1290.34' 14,492.56 7,410.40 11,388.25 1,792.66 Hold for 20' 14,512.56 7,411.45 11,405.87 1,783.26 Start 3°/100'DLS,0°TF,for 122.07' 14,634.63 7,413.94 11,513.54 1,725.84 Hold for 6363.76' 20,998.38 7,340.40 17,128.32 -1,268.53 TD:20998.38'MD,7340.4'TVD Checked By: Approved By: Date: 8/17/2015 11:53:32AM Page 9 COMPASS 5000.1 Build 74 • • cu Z "2.- = I ° N ry U C +■ o a U ci a O y O N C M O 0• O Cl to O O T, 0 W a /\.... w U 0 O o aii CU M 2 o u o ild m o (an �� O U o 2 C N ra m t L o .3 N Q T O N i L O715 /1\ N T w u n� Cl) / = c o 0 3 � a, 1. - a Om = C a s v o o 73 a ii min CD Li- <a 0 L @S v Q 0+ •Cl) C M M U W ,^ W W 0 v ■— .K Q st 7 Q r J O t � Cf) Lo ° � 0 O M 0 O L 0 c N • x 3 0 0 ` C O • o V Z C Ln O Q N O a N U m J N O C ,Q. o I 3 i V .. 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LO z aa) N C1 L 0 a N 0 Z rLi) 6) 6) L m 0 0 0 0 N N (/ _ O O c O a) U y ❑ ❑ M O O o 0 m 6) C N �+ ° LL R LO LO o ❑ ❑ ❑ ❑ U U m m ❑ ❑ O o w CO CO v v v v a) a) o a L c ai $ as a U U U U (6 (n (n (n U U LL .0 N N V V o U N N `C a) m a) 7 O 3 Ti, ,- ,- N M M M M W W N '9 Q au U v n v v A LA° ° C as n ai w a) (03 0 w00 Et x a a Co E 0000 U U U U.. .. .. .. 00 o 0 N 0 2 L0 O u) o Z EEE c m m (0 (0 c C `o a. a 0N`) (ca a) = a 0 N N _ a3 a3 CO a3 a a a a 10 (0 0 O N iq 3 N U 0 m m d d d d , a 0 O m c = 2 0 N t , N La La (O (O i i (0 U U II (0 h C C N- [- N NCr) 6) (0 N CO C C ,V) Z 0) O N C s- r COM COM COM COM 6) 63 E (Oq a) a) `O c O0) V) (0 O N a) y (n (n (f) (n (n (() Ln L) (n (A Q w CD0 a) m m E 000000 0000 m = y 3 m °o Q C a 7 t6 O. U U U U U U 0000 U U U OC m LL U C.) > 0 C C y E c c c c c c C c C c aa.) o c C r, 0 CO CO 03 a) CO CO a3 a3 a3 (0 N N a, 0 .O +' 0 1( in V a a a a a a a a a a N (6 C N C > w m (co ° a a u) a(Q) y Q m I- K U) to W U o 0 U a • 11:58, August 17 20'5 CD5-03w 08 Lad e r View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a a u'e�3 3 ®o®® O a a CAM 00ctao 0 0 0 300 1 i fi 'I' I I C 0 Q II t �/� �I l l19l ea(nC150 IID �'I� I iili[IlJIld1lllil N [Ivo' ilI IA,¢' U o ', ..(7-.) I / Ir 'HI l 11 U '1111 pl'0 IllIII��,V,:. ..... .. _ Equlvelant Magnetic Distance I I I I I I I I I I I I I I I I 0 3000 6000 9000 12000 15000 18000 21000 Displayed interval could be less than entire well:Measured Depth 36.30 To 20998.38 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 36.30 800.00 CD5-03wp08 (Plan CD5-03) GYD-GC-SS 2159.40 2400.71 10-3/4" x 13-1/2" 800.00 1800.00 CD5-03wp08 (Plan CD5-03) MWD 7410.40 14492.56 7-5/8" x 9-7/8" 800.00 2400.71 CD5-03wp08 (Plan CD5-03) MWD+IFR-AK-CAZ-SC 7340.40 20998.38 3-1/2"x 6-3/4" 2400.71 3900.71 CD5-03wp08 (Plan CD5-03) MWD 2400.71 14492.56 CD5-03wp08 (Plan CD5-03) MWD+IFR-AK-CAZ-SC 14492.56 15992.56 CD5-03wp08 (Plan CD5-03) MWD 14492.56 20998.38 CD5-03wp08 (Plan CD5-03) MWD+IFR-AK-CAZ-SC 18 s .s 6 3 ss 3 3 Es o a a a a w3 0 0 0o as 60^ - rim-' j// o // IJj a) __.---7:____—.— // N I � 30— / .. U 0 c ; U 0 r t-- t I-' I - r. t.. -r I I I I I I I I I 1 1 I I 1 I I I I 1 1 I I I 0 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth 0 CD5-03wp08 MD Inc Azi TVD Dleg TFace TO 350 540 36.30 0.00 0.00 36.30 0.00 0.00 36.30 To 20998.38 350.00 0.00 0.00 350.00 0.00 0.00 540 740 600.18 3.75 340.00 600.00 1.50 340.00 1288.98 20.93 348.28 1270.40 2.50 10.00 740 930 12:02,August 17 2015 1396.04 20.93 348.28 1370.40 0.00 0.00 930 1120 g 2400.71 54.06 9.67 2159.40 3.50 30.85 CASING DETAILS 2420.71 54.06 9.67 2171.14 0.00 0.00 1120 1320 2685.40 63.10 12.01 2309.00 3.50 13.07 TVD MD Name 13202.22 63.10 12.01 7066.78 0.00 0.00 1320 1510 2159.40 2400.71 10-3/4" x 13-1/2" 14492.56 87.00 331.93 7410.40 3.50 -65.06 CD5-03 01.Heel 062515 DK 7410.40 14492.56 7-5/8" x 9-7/8' 14512.56 87.00 331.93 7411.45 0.00 0.00 1510 1700 7340.40 20998.38 3-1/2" x 6-3/4' 14634.63 90.66 331.93 7413.94 3.00 0.00 20998.38 90.66 331.93 7340.40 0.00 0.00 CD5-03 02.Toe 062515 DK 1700 2500 SURVEY PROGRAM 2500 3300 e7 Fr3. Oep49 44 CO5-93 Plan Tool 30.00 800.00 C05-93,08 (Plan CD5.83) GYO-GC-55 3300 4100 086.00 1400.71 205-039988 (Plan C05.03) M. 080.88 1980.71 C05-039908(Plan COS-03) M•O*IFR-AK-CAZ-BC 480.7+ 3988.71 C05-83m8(Plan CD5.03) MM 4100 4900 2 1492.71 14492 56 C05-83x90418 (Plan CDS-03) MMO4IFR-4K-L42-SC 14492.58 20998.38 C05-03x908 (Plan C05-03) M +9992.58 20998.38 LD5-03W08 (Plan CD5-93) M4DJO*IFR-AK-CAE-SL 4900 5700 5700 - 6500 6500 .... ......... 7300 7300 8100 8100 9710 0/360 9710 -� 11320 225 11320 12940 -30/330 210 30 12940 14550 14550 16160 195 16160 17770 180 17770 19390 165 19390 20998 13 -60/300 (115.0 120601090 75 60 - r / `y//��`n�',7%> jt1`` ' CD5-02wp07 CD5-09wp09 _i:ee `f� , t, f 'I. *� e•�r �i,4 i )�p �(�t�ttirt r1 iJiEL. //( - ,�c 411' `y�y a S.'<e�t% \ �l,A�, a vti�104.4w)� i-���/ diti ICI 'fib 110f \A y7,*',�`'s 1d i {ad �����' -90/270-. „ - � �� .01 90 -� //IaIll � c��� '�,tl� t T�s�.. i� � t �\, is CD5-12wp07 14.,,,41,:',i,,:.,.•!.,X/I' ►►i \ '74 i :i I�iA�.� _CD5-01wp07 CD5-06wp07 •r ,r 4' X4,3, .. ,,...„:04. r,:,,,,:. .., vttll loc,Uy vv� _pizi,,rim,, ,.„, ___. �w clFRi '',..0.41-00.4. 7/ lak CD5-314PB1 '; _.N.0 7,,,/l .'04674,,,V--. 4 6 .0 rri3O ..�Viv d...,j o . w�sft,d...- 4. 1. LK',y, -120/240 :fit o„ r ig.701 a,►..�agiZia.�I 120 }; ,arPY \ ♦-`.tram ✓ 5t " , ✓fir�4A tlt,r„,,e4w 0,4`1 0- 4.Y.,"�; wa ` fli i Aft /�„i•t�l CD5-313PB1 ®lk eaAw.. irri :®`v> •d►%�,►.- ...MK �i r/�s ear f.0 A I ♦ a1 W, \ �ii✓ V \ 1 °`;ll � Kiri,//il''F� 46 VArm' v4j ° .- ° 1eolea1•/% v'004,•/ CD5-313 m ,w.®nc, .v.i\„II'�1 !;��*l� Ij���► ����I�j . < iii®j>? i .'':: • • Northing (5000 usft/in) i , 11111111111 , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I I 1 1 I I 1 I , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Jill 1 1 - 73 - - CI - rZ - - N - - c — Q - - CV - _ 0 - 0 - o - a - -o - _ n — — Uoa - p m n U o a — 0 3 0-3 — U i!I ch �' r 14- 8 * p o co ��.��_� U W - o- , 123i - — p r — 3 - o Ur r - �n U o d- ; — U {n - - N 0 - - C - - Q — <C.- - - Ll) - 0 - 0 - y_ - - w - ..a - - .,V)V/ i W c — to 0 a Z I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 I 1 1 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 3 (uI/jsn 0005) 6u!4;aoN 0 AC Flipbook o °0 0 o 0 0 0 0 0 0 0 0 0• 0 rn 0 0 0 0 0 0 d0- 0 N O 0 0 0 r0r1 0 0 0 0 0 0 n M M r , a o M Ln r\ rn N. 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N. 1- rn M rn O O Q O O O N N k..00 0 O- 01 O� b4 i im" 0 0 000 00 rn rn NT" 4 MMMrn 0 O M M M M M rn M O rsi V •riN ,_ r0n0 -00 C 0 r\ Nd0- N � � LOm 0 •0 0 0o O 0 •[.r\ N N N d- CO M rnm � ON � � � � m 'r' - � rn r r N N r. d-' d- O `- N II0 O 00 0O O O O NOO 0O0 d- N. 0 0 O 0 0 N r 0 0 O 0 0 0 0 M .O N. M O1 r( . N rn in (n 1-r) n N 0 rn L N. - d- d- in .0 N. c0 61 - N 1 1 qO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M In dr en N N - 0 0 0 0 0 0 0 0 0 T- N d" Ln .O N. O1 rn V1 N. ON r- M N. in rn - a N. Ln rn •- n rn O1 Ln ¶-- N. rn 1. 1'-' N rr N- Ln .0 1. O> N d" N. 01 ,- e- C- r c- 0. r V V V 7i- 8 8, �i4Pi�Ii��,itiil'.1 0 Y Y Y O ,�"oiro-I���''I,1,1 N 414113-41142;014P 441,0 00000a t. Lloa0000a N#4 �414si v 111:" . ,�S,' Jib, �.mm m � 000000a d a 3 3 3 3 3 3 3 ` / ��! > m m m m 0 m m0 A iü vv ��hi\� � 0 ao0 ��� 00oArlO O O O ,, __.. �i \ � �P O I� r l 00 ,O rf1 ,ArkujeAle VII � \11 `�``�� fid%, *WO! ;4;.4:7: , -.' (4 1 ii r 1 oF.. , 10 I' �o i kJ °a vv _ 0 N I O o O CO O O .. O O O N ory CI. O N4-1 VI M O 'N 0 0 oCOCO N. N7 MMM O O Q O O co N N ..0 .0 0 O1 01 I 0 O O O CO CO 01 O1 NCr 7r 71- N .- r- r' r- M M M M Q CI O M M M M M M M ON • 0 0 0 00 00 ' r ' 0 N M cO ni V 0 M O ` ' a 0 d V\ Ln M 0 .0 O O 00 .0 O O Ln N N N Cr c0 N c-- ,- Cr 0 `- N o o 0 0 0 o 0 0 o O 0 0 0 ON O 0 O O 0 O O 0 O 0 O a L` \ N C-\ d, t, d- [t- M N N M tI, I� Ln M a\ r, LI'. rr\ N- I, N d- 'D N. 01 0 M L!1 N. C r c- •-- N M Lr\ r\ o0 e-- c- e- e-- N i �0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M Ln - Cr M N N • 0 0 0 0 0 0 0 0 0 - N Cr. in n 0'. M in r. ,- rn trN r, Ln M c 01 f� Lr\ M - N. M a\ Ln c- N. M r- N M Lr\ � cc d, ,- N N. a, r r ,— r e- 0 VV N - N p 0 Q Q Q N OC C K `Y000000 \�r.. l E \ X/ \y il o000oN� \ a �aa�� ITN a 6 66616 ,! ., \ ,� �, V V V V V V V X/ C C C C C C Clc ' \ ^ / /! \ _6!.11.11111 a 3333 T\ / / 0 0'31`�'0 0 o jt ^^ � �.. � � , i0000000 .. f r �\ �V�VVVVV ``^ / a -\-- \..\11: { o air I ' ice, Q LL,.mlo UI,, vl� o o 0 OT ,/O� NOS 0 �/0 /o W s mo mo a a v v M V N V./ r 1 / 1' 1 qD C a 0 O e,. a \, / f m Z .6 s a max., an V �Tm', „,,/ 0 AoV”` • rn N Co t M 0 0 • ---'--:---.. \\ ---....'-‘'\ N 0 _ d' 0 O o a, 0 N 0 0 CI o ri t p t r 0 N o o oc000 r. rr- MMM CD 1"' < O O O N N O. 0 C 01 C • 0 0 0 00o c0 O' d� N N 1- r- r- Q 11"1 d.. � c M M M rrl Q M M M M M M M 0 O 0 p 0 0 00 00 Cr ' r' 0 N ' 1/40 M CO N V 0 M 0 - C.or 0 .7t- N Lf\ L(\ �O M O 0 co O 0 LAN0 N N 00 o M M 0S coN Cr\ ' 1/40M 7r- � 0 rn tVN N c- c-- d- 0 c-- , N pro 2/5--J-1- Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, October 29, 2015 9:05 AM To: 'Knock, Douglas G' Cc: Dai,Weifeng; Bettis, Patricia K(DOA) Subject: RE:Qannik Interval in CD5-03(PTD 215-146) Follow Up Flag: Follow up Flag Status: Completed Doug, We have reviewed the logs for the Qannik interval and require that the Qannik to be cemented in CD5-03. If you have any questions, please let us know. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From: Knock, Douglas G [mailto:doug.knock(aconocophillips.com] Sent: Monday, October 26, 2015 1:53 PM To: Bettis, Patricia K (DOA); Loepp, Victoria T(DOA) Cc: Dai, Weifeng Subject: Qannik Interval in CD5-03 Patricia,Victoria We drilled across the Qannik interval in CD5-03 yesterday. The Qannik interval in CD5-03 reaches a maximum of 9 ohms resistivity. Low resistivity is mostly due to high clay content. To date, we have not cemented the Qannik when it is below 10 ohms (see attached slide). We use 10 ohms as a pay cut-off in lieu of density information(no density on CD5- 03). We request to not cement the Qannik interval in CD5-03 Please let us know. • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-03 Plan CD5-03 Plan: CD5-03wp08 Report - Errors 17 August, 2015 Multiply by 2.58 M 0 Schlumberger III Report-Errors Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 1 Site CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Well Plan:CD5-03 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 34.10 usft Wellbore Plan CD5-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) B G G M 2015 11/6/2015 17.93 80.83 57,471 Design CD5-03wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.30 0.00 0.00 331.00 Survey Tool Program Date 8/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 36.30 800.00 CD5-03wp08(Plan CD5-03) GYD-GC-SS Gyrodata gyro single shots 800.00 1,800.00 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 800.00 2,400.71 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,400.71 3,900.71 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 2,400.71 14,492.56 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,492.56 15,992.56 CD5-03wp08(Plan CD5-03) MWD MWD-Standard 14,492.56 20,998.38 CD5-03wp08(Plan CD5-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey ,:Multiply by 2.58,; MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 36.30 0.00 0.00 0.00 -34.10 0.00 0.00 0.00 350.00 1.15 0.00 0.00 279.60 1 15 0.41 0.41 KOP:Start 1.5°/100'DLS,340°TF,for 250.18' 600.18 1.16 3.75 69.60 529.60 115 0.77 0.77 Start 2.5°/100'DLS,10°TF,for 688.8' 1,288.98 1.24 20.93 166.87 1,200.00 1.13 2.12 1.26 Hold for 107.06' 8/17/2015 12:07:34PM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 1,342.51 1.24 20.93 167.12 1,250.00 1.14 2.62 1.36 Base Permafrost 1,396.04 1.24 20.93 167.12 1,300.00 1.14 2.62 1.36 Start 3.5°/100'DLS,30.85°TF,for 1004.67' 2,400.71 1.81 54.06 178.85 2,089.00 1.35 4.46 2.04 , Hold for 20'-10-3/4"x 13-1/2" 2,420.71 1.85 54.06 178.91 2,100.74 1.31 4.56 2.06 Start 3.5°/100'DLS,13.07°TF,for 264.69' 2,685.40 2.13 63.10 4.37 2,238.60 1.46 6.72 2.07 Hold for 10516.83' 2,710.60 2.14 63.10 6.04 2,250.00 1.66 7.97 2.26 C-30 5,867.11 2.46 63.10 10.44 3,678.00 5.45 19.66 6.21 K-3 6,353.41 2.53 63.10 10.65 3,898.00 6.19 22.16 7.03 K-2(Qannik) 7,153.59 2.65 63.10 10.88 4,260.00 7.39 26.18 8.35 Albian 97 9,244.67 3.00 63.10 11.22 5,206.00 10.55 36.79 11.86 Albian 96 13,202.22 3.74 63.10 11.47 6,996.38 16.46 56.62 18.44 Start 3.5°l100'DLS,-65.06°TF,for 1290.34' 13,291.87 4.66 64.46 11.47 7,036.00 16.61 56.97 18.61 HRZ 13,397.14 7.04 66.14 11.43 7,080.00 16.76 57.06 18.85 Kalubik 13,809.56 21.89 73.42 10.93 7,223.00 17.56 55.14 19.76 Kuparuk C 13,816.59 21.89 73.56 10.93 7,225.00 17.56 55.14 19.76 LCU 14,184.26 30.53 80.73 10.36 7,307.00 18.06 52.48 19.51 Alpine C 14,203.27 33.26 81.11 10.13 7,310.00 18.23 51.39 19.32 UJU 14,443.47 38.21 85.99 9.63 7,337.00 18.56 48.98 18.96 Alpine A 14,492.56 38.21 87.00 9.63 7,340.00 18.56 48.98 18.96 Hold for 20'-7-5/8"x 9-7/8" 14,512.56 38.30 87.00 9.63 7,341.05 18.55 49.12 18.96 Start 3°/100'DLS,0°TF,for 122.07' 14,634.63 38.54 90.66 9.10 7,343.54 18.56 50.03 18.49 Hold for 6363.76' 20,998.38 38.71 90.66 177.58 7,270.00 21.91 71.85 21.85 TD:20998.38'MD,7340.4'TVD-3-1/2"x 6-3/4" 8/17/2015 12:07:34PM Page 3 COMPASS 5000.1 Build 74 0 Schlumberger 0 Report-Errors Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-03 Project: Western North Slope TVD Reference: Plan:34.1+36.3 @ 70.40usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.1+36.3 @ 70.4ousft(Doyon 19) Well: Plan:CD5-03 North Reference: True Wellbore: Plan CD5-03 Survey Calculation Method: Minimum Curvature Design: CD5-03wp08 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') C) 2,400.71 2,159.40 10-3/4"x 13-1/2" 10-3/4 13-1/2 14,492.56 7,410.40 7-5/8"x 9-7/8" 7-5/8 9-7/8 20,998.38 7,340.40 3-1/2"x 6-3/4" 3-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (") (°) 6,353.41 3,968.40 K-2(Qannik) 14,184.26 7,377.40 Alpine C 9,244.67 5,276.40 Albian 96 13,397.14 7,150.40 Kalubik 13,291.87 7,106.40 HRZ 1,342.51 1,320.40 Base Permafrost 7,153.59 4,330.40 Albian 97 13,809.56 7,293.40 Kuparuk C 2,710.60 2,320.40 C-30 13,816.59 7,295.40 LCU 5,867.11 3,748.40 K-3 14,443.47 7,407.40 Alpine A 14,203.27 7,380.40 UJU Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,340°TF,for 250.18' 600.18 600.00 7.70 -2.80 Start 2.5°/100'DLS,10°TF,for 688.8' 1,288.98 1,270.40 150.39 -35.75 Hold for 107.06' 1,396.04 1,370.40 187.83 -43.52 Start 3.5°/100'DLS,30.85°TF,for 1004.67' 2,400.71 2,159.40 783.21 -10.63 Hold for 20' 2,420.71 2,171.14 799.17 -7.91 Start 3.5°/100'DLS,13.07°TF,for 264.69' 2,685.40 2,309.00 1,020.71 34.74 Hold for 10516.83' 13,202.22 7,066.78 10,194.52 1,986.25 Start 3.5°/100'DLS,-65.06°TF,for 1290.34' 14,492.56 7,410.40 11,388.25 1,792.66 Hold for 20' 14,512.56 7,411.45 11,405.87 1,783.26 Start 3°/100'DLS,0°TF,for 122.07' 14,634.63 7,413.94 11,513.54 1,725.84 Hold for 6363.76' 20,998.38 7,340.40 17,128.32 -1,268.53 TD:20998.38'MD,7340.4'TVD Checked By: Approved By: Date: 8/17/2015 12:07:34PM Page 4 COMPASS 5000.1 Build 74 • • o ` �O O BOJ Vii/ _ `7 O { / 4- Cit=311KS N cl T �0 .eoz OJ `. s OJ J OJ c.` J `� fid; 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I� U U) O M_O U O 00 i CD2-78 j (C) CD5-04 00 O o o C M Oco ' 1 -O oe 0 O O 1 Q 1 N O O O O O O r--- LIldeCI Pa! JGA anal • • • M • - • • Ll J 6........••'-' ''.„.. , • y. O U , • • Q Cl N .. . .. y a:) , . , . .. O .... ... ... ...,,....... . Thiii:L ...... . ..... '.....„. , • • M O • 0 V • • • .i 0 • CD5-03wp08 Surface Location M. CPAI Coordinate Converter , From: To. Datum: NA6e3---,i Region: I alaska . Datum: INAD 27 Region: lalaska . C Latitude/Longitude 'Decimal Degrees ----A r Latitude/Longitude 'Decimal Degrees 2:1 . , 11 r- UTM Zone: 1 r South C UTM Zone: True 1- South ( State Plane Zone: iiE Wits: ul - r State Plane Zone: [True ,...' ,. Units: Jus-It . i Cal Description Iti/i.D27 only) 6 Legal Description(NAD27 only) Starting Coordinates: -- -- Legal Description X: 11489534.00 Township: [Oilm rizi— Range: j004 ITD, Y: 15965650.92 Meridian: lu j Section:J18 , .......____ FNI--- 1304.16635 ITEL—il 12478.2328 Transform i _....:Qutj Help CD5-03wp08 Intermediate Casing I 1 , :.- ,,,, ts CPAI Coordinate Converter From: To: Datum: INAD83 2 j, Region: lalaska J Datum: INAD27 .,-] Region: )alaska 1.1 r Latitude/Longitude oecirnal Degrees Lvi r Latitude/Longitude [Decimal Degrees zi r UTM Zone: South[------- r- , 1 r UTM Zone: !Truef- South 6" State Plane Zone: ii—E, Units: IZAT.Ii" .E !True r State Plane Zone: 1 id Units: ;;TTE,. r Legal De,,,cription INAD27 only) 4Legal Description(NAD27 only) 1 Starting Coordinates: Legal Description X: 11491555.00 Township: 1012 ItT .-AIr Range: 1004 ITE Y: 15977000.00 1 Meridian: ju ...7i Section:13i 14756.1157 ITEL: J 1640.71995 11 r [ Transform -, 1 Quit Help I .I • 0 1 CD5-03wp08 TD MCPAI Coordinate Converter ). t 1" v From: ; To: DatumNAD83 Region: alaskai r Datum: NAD27 [ Region: lalaska w1 C Latitude/Longitude [Decimal Degrees Lid C Latitude/Longitude !Decimal Degrees A C UTM Zone: E South I C UTMZone: True fl South t+' State Plane Zone: Fs---;3 Units: us ft C State Plane Zone: True . Units: us•ft t" Leaal I)extiptiOrf 4v ii 4. Legal Description(NAD27 only) ....___] Starting Coordinates: .--_- .. Legal Description X: 11488610.00 Township: 1012 Nj Range: JED. [.... _ Y: [5982800.00 Meridian: Iu Section:130 FNL 14295.6484 FlitDr 1367a3562 Transform —1 Quit 1 Help 1 • • Tollerable Collision Risk Worksheet As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY • APP DESCRIPTION 1 ##/##/15 CZ DB C.A. UPDATED PER K150003ACS ALPINE SATELLITE DEVELOPMENT IwN `� Ai • � � !IN • LOCATION OF - r y� '"� THIS SURVEY iC1p� N 0 , � 4A/ CD5 .* • CD4 TO ALPINE / 1 .' �M 0 µ . •••0 ACCESS ROAD , n p _oa iraraiiN121rolio�' � ! c) .......tia‘Amor—At, MIRBrai ' � PR(6401f = 14 iii ra z a " L TE ` j 011111 VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 7, T. 11 N., R. 4 E., U.M. SECTION 18, T. 11 N., R. 4 E., U.M. CD-5 SNOp�pER c)' PP 02o00��Qo PAD 'DEs\G ��oaQaa,9�°%Q L%N oo��o9,Lr\ fQ•_. • 1� ♦ • A PLANT N ASPC N 0 0 15'41 52" -Q _....k\ 111.____ �O KUUKPIK I z ALCMFU. ,,,,, .. ne q�h.-e+vs+w.rwrPW!�wr Alpine Survey Office yV- ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. DRAWING NO: I PART: I REV: 14-12-09-1C ##/##/15 CE-CD50- 1 OF 3 1 REV DATE BY CK APP • DESCRIPTION REV DATE BY • APP DESCRIPTION 1 ##/##/15 CZ DB C.A. UPDATED PER K150003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC. 18, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FNL FWL GND PAD CD5-x01 5,965,661.64 1,489,572.44 70° 8' 49.155" 151' 13' 21.378" 293' 2489' 27.6 34.1 CD5-x02 .5,965,656,28 1,489,553.29 70' 8' 49.099" 151' 13' 21.934" 299' 2470' 28.1 34.1 CD5-x03 5,965,650.92 1,489,534.00 70' 8' 49.042" 151' 13' 22.493" 305' 2451' 28.4 34.1 CD5-x04 5,965,645.24 1,489,514.77 70' 8' 48.982" 151' 13' 23.051" 311' 2432' 26.6 34.2 CD5-x05 5,965,639.80 1,489,495.46 70' 8' 48.925" 151' 13' 23.611" 316' 2412' 28.1 34.3 CD5-x06 5,965,634.56 1,489,476.20 70' 8' 48.870" 151' 13' 24.170" 322' 2393' 27.7 34.3 CD5-x07 5,965,629.08 1,489,457.08 70° 8' 48.812" 151' 13' 24.724" 328' 2374' 27.9 34.3 CD5-x08 5,965,623.88 1,489,437.69 70' 8' 48.757" 151' 13' 25.287" 334' 2355' 28.1 34.3 CD5-x09 5,965,618.27 1,489,418.53 70' 8' 48.698" 151' 13' 25.842" 340' 2336' 27.3 34.2 CD5-x10 5,965,613.12 1,489,399.13 70' 8' 48.644" 151' 13' 26.405" 345' 2317' 28.1 34.1 CD5-x11 5,965,607.66 1,489,379.86 70' 8' 48.586" 151' 13' 26.964" 351' 2297' 27.9 34.1 CD5-x12 5,965,602.23 1,489,360.56 70' 8' 48.529" 151' 13' 27.524" 357' 2278' 28.0 34.1 CD5-x13 5,965,596.59 1,489,341.43 70' 8' 48.470" 151' 13' 28.079" 363' 2259' 26.1 34.2 CD5-x14 5,965,591.36 1,489,322.33 70' 8` 48.414" 151' 13' 28.633" 368' 2240' 27.6 34.2 CD5-x15 5,965,586.10 1,489,303.11 70' 8' 48.359" 151' 13' 29.190" 373' 2221' 26.8 34.2 NA! NOTES: / KUUKPIK 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. r' 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) .`' Alpine Survey Office 1111..7 ' ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE-CD50-### 1 OF 3 1 REV DATE BY CK APP i DESCRIPTION REV DATE BY • APP DESCRIPTION 1 11#/##/15 CZ DB C.A. UPDATED PER K150003ACS NOTES: 1 . ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-4 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, JUNE 2013. 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD5-X12, CD5-X13, CD5-X14, CD5-X15, 4/10/15, FB 2015-12 PGS 4-7, 9; CD5-X01 THRU CD5-X11, 4/17/15, FB 2015-10 PGS 49-52; SURVEYOR'S CERTIFICATE , I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED .4•7\*••OF' A�:4S�./ AS—BU TO PACTICE TILT REPR SDENTSRA SURVEY MADE VEYING IN THE TBYEMEE OR�UNDER OF ASKA, HMY DIRECT • AT THIS • `'�•'''• ••''.9 �1 SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST ��� 4AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE *� 49th �� •* 0 CORRECT. • / DATE: REGISTRATION NO. LS-5077 • 0 Donald G. Bruce : oiir •O f No. LS-5077 '<�`"� • �P ••• KUUKPIK FESS 44 I 1CM F .. xeesar,w,.&Wrap,Nicks MI5•(8o)asaw Alpine OHlce (917 6]0-<Ti9 Alpine Survey Office ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE—CD50—### 1 OF 3 1 • • Häagen Dazs Necessary Plan Request (NPR) • 0 Initiated by: Doug Knock Date: 06/25/15 Contact Information: 907-265-6506 Need by: 07/10/15 Monday'Today" for Event: FEL3 Well Name:CD5-03 Placeholder Well Name: Bottom Hole Location Name Last Plan Number(prior to this change request):wp X;. As-built available?Yes As-built attached? No Slot/Surface Location: 3 Y/N: 5965650.82 X/E: 1489533.91 Z:above MSL NAD: 83'2" Rig:Doyon 19 Doyon 19 Air Gap: 36.3 Inclination Profile:Horizontal Pilot Hole?: No Laterals?: Single New Hole from:Surface Number of Hole Sections: 3 Strings CI C Conductor x Hole MD/TVD Depth Type Formations Depths BHA Base Permafrost 1250.00 ND5S Max Dogleg: C-30 2250.00 NDSs Dogleg Lunt Steering in this Hole Section?: Nerve K-3 3678.00 Noss K-2(Qannik) 3898.00 Noss u u'-' Albian 97 4260.00 NOSS r r' Albian 96 5206.00 Noss f f''". HRZ 7036.00 NDss a a';., Kalubik 7080.00 TVDSS c c'.'. Kuparuk C 7223.00 TVDSS e e 10 3/4 x 13 1/2 2089 -,[, LCU 7225.00 NDSS Alpine C 7307.00 Noss UJU 7310.00 NDss Alpine A 7337.00 TVDSS lir Iii iiii iiii iiii BHA Pump Tangent No/Yes Max Dogleg Him Dogleg Limit Steering in this Hole Section?: No/Yes iii Topof Pool/Production Interval: r ' r; Kuparuk C 7337.00 rvoss 1111', Bottom of Pool/Production Interval: Name MD/TVD Dep'- 75/8 x 97/8 7340 TVDSS 87° Targets V/North X/Eest Z/Depth N-Radius Inc° BHA i heel 5977000.00 1491555.00 7340.00 TVDSS 100 ft 87 ° Max Dogleg: toe 5982800.00 1488610.00 7270.00 0/055 100 ft 90 ° Dogleg Horizontal By: 7350 Noss 90° .a,y. ...„,o Lineup with Toe at Heel? No/Yes „ Bottom Hardline: Non pay 7355 TVDSS 90° _ i ! Liner x Hole Geology/Reservoir Contacts:First&Last Name(s) Drilling/Completion Contacts:First&Last Name(s) Well Planning Contacts:First&Last Name(s) Approved by: First&Last Name Date: mm//dd/yy Contact Information: ###-###-#### {y end to — PROPOSED WELLS Qter" QCPAI OPERATED UNIT Operator 'DL38 48 66� 1 E 1 CPAI LEASE with ADL#, and Filet � CQ Qom' � 300634 c). � �o� ��, C0► L ILLE '� RIVEti UNIT ASRC-NP 1 ASRC-NPR2 ASRC-NP ASRC-NPR,. 0 ., nQ QcS% 17 Q O� I ADL387207 c5` 932191 .1 N. 47 58 NPR - A CD 0: (5‘ c, 0 0 b AA092347 - (:),,, Qv, ! 'SRC-NP'- 340758 Q O %-...,..-......., > -I..- -.. 1 -‘,. ''.. A DL380075 •32034 A - -NPR2 DL380077 2036 AA09234 ADL38720 340757 O 932193 li C, ASRC- PR4 � Q a, ConocoPhillips V' Alaska, Inc. Proposed CD5 Wells With N Leases 3-19-2015 AA081817 ( 0 0.5 1 932552 A 1111111111111=1C1 Miles • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • S TRANSMITTAL LETTER CHECKLIST WELL NAME: C1 k. CSS' 0 3 PTD: 02)5-` Pi C• Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: 61i'1L ?t J&r POOL: (i JVt I/ /�M.r1 Ale nf. GI/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: Well Logging Requirements ✓ Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 i • 00 T N a) a N N $ `m a as, 5 . _, Tu E ca N, Q a , , , v°O' Oc m , , ; c , E M , o. E a 1) rn o a co , I a n L O. a O, E O O' • O. a 0I oa ao co o ° . Nco . m. 3. To co a a. 0) '3. o a -°' 2 a 2' o mil CO. O' co •`� N' -C >. o LL1, O• : W. �. . U . o o, .N co 3, . a co, a co,, a a' 0' j Z a, .C> °� CO a). , co o co, w. 0. , v c ' • W. W c N cn, �, �, a U a m, o C�. 3. E' Q 3 N CD C, .N+ N :00: �� 3, y. y. N y, ` c, va) o. o. N. O i a) Q, a) Q Q, M. co o •N N. CO' C. a)' c. >. 2. co N N ., o. W J• L. 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