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216-111
ConocoPhillips April 23, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Report, First Quarter, 2019 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 r APR 2 4 2019 AOCCC Please find attached the first quarter 2019 annular disposal 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 first quarter of 2019, as well as total volumes disposed into annuli for which disposal authorization expired during the first quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, A(�- a9, G. L. Alvord Alaska Drilling Manager R o_ J Q CO co 20 o C- U (n Z Q Q LLJ>a � J c Z Z 0Z U) (DLL 00 z LL Q r _J 00 W VQ Q i Q) U m W O N a p N o v a o � o Q Q Q Q Q a. Co N ` E N Z Z Z Z Z vs.. O CO O 'oLL N a� N w m o� N E a z co O LL N () O J C O C N a r r > C) M '0CC) C'a]b N Io U o❑ N Q Q m a ° Q Q 3 N n ❑ '� Z .� a C .. v W _N N Q O w G D E O O L` mM Z O y ui m - m :s —C, O I..i. O E w❑ O G p O _ �° o rn N o N LL E Z Z a n c Z Z Z Z O O a ❑ N N O a Q iLL 'om N N co of of m Q V O O O Q 9 o �a m ❑ w E a T o O o o N nl v❑ _a ❑ a O Z a 0 J ❑ W W❑ N O O O O C11❑ > E LLN] ❑ > m U o M Z CD > `m O :c N 0 ❑ O rn❑❑❑ v C O a U N U O N Y - afO �' ❑ O N Ea N Z N ON U N c r N ❑ E Wm a c O N O O O O O Qj N v, = Leo M Lo �❑ MOa.n _m U r d 3 _ >O N C Z Ul ¢a _ T a ❑ 0E > ❑ m O E C O Q U LLa m o = c 3 0 0 0 0 0 o (D m o m a a) g Q a s E w ❑ v N "Op L LL a � O ❑ x U �' J O m E E oc U O �J y o m oEl ^ c v c y c cl 165 L U O r O Q c � N m ro ro m m 19 F c o a Q K v v rn W> d s N d N RECEIVED FEB 0 1 01Q, AOGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL �I1--St 1 S 3/p,-022 2/fs/2-0tq 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 216-111 ConocoPhillips Alaska, Inc. Development 2 Exploratory ❑ 7. Well Name: CD5-18 2. Address: 4b. Well Status: Oil Q Gas ❑ WAGE] 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20750-00-00 3. (Check one box only)N„(r 5a. Sundry number: 5b. Sundry approval date: 9, Field: Initial Disposal [ —or Continuation Zor Final ❑ 318-022 2/15/2018 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): 0 0 396.75 396.75 1 12/17/2016 12/17116 LOT/Freeze Protect 2018/1st 0 0 5.25* 5.25 1 2/21/2018 2/21/2018 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 1 0 0 0 0 0 N/A N/A N/A Total Endingo Report is due on the 20th Volume o ao2 ao2 2 of the month following the final month of the quarter. Ex: (bb April 20 for the first quarter, July 20 for the second quarter, 11. Attttaa ch: Disposal Performance Data: Pressure vs. Time ❑ step Rate rest E -October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): * Diesel Freeze Protect / In'ecti test I hereby certify th/a,A't the foregoing is true and correct to the best of my knowledge. Signature: �r 6-0411k Chip Alvord Date: t { 1 Zp (cr Printed Nam/e:v_ G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 Form 10.423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE pgpSubmit in Duplicate �n-� (`�'(� F --n1 g ?n19 ConocoPhillmd" 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 j, -1ED FEB 01 2019 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: 216-111 ConocoPhillips Alaska, Inc. Development ❑Q Exploratory ❑ 7. Well Name: CD5-18 2. Address: 4b. Well Status: Oil ❑� Gas ❑ WAGE] 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20750-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g, Field: Initial Disposal ❑✓ or Continuation ❑ or Final ❑ 318-022 2/15/2018 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(bbis): 0 0 396.75 396.75 1 11/2/2015 12/15/2017 LOT/Freeze Protect 20181lst 0 0 5.25* 5.25 1 2/21/2018 2/21/2018 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 N/A Total Ending Report is due on the 20th volume o 0 402 ao2 2 of the month following the final month of the quarter. Ex: (b51s): April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): * Diesel Freeze Protect / lnjectivty test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Chip Alvord Date: Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD5-18 Permit to Drill Number: 216-111 Sundry Number: 318-022 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov 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, Hollis S. French { f Chair DATED this (5 day of February, 2018. RPD^^.S Gam- FID)Z 6 2018 STATE OF ALASKA ECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSI N ANNULAR DISPOSAL APPLICATION N 18 2018 20 AAC 25.080 �S A lS J ) V I . Operator 3. Permit to Drill Name: 1 _ 1 ConocoPhillips Alaska 4. API Number: 50-103-20750-00-00 - 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD5-18 ' 6. Field: Colville River Unit- Alpine Pool ?. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, C05-11, CD5-12, CD5-17, CD5-19, Torok and Seabee formation, shale, siltstone and sandstone C1015-20, CD5-21, CD5-22, CD5-99, CD5-313, CD5-314X, CD5-315, CD5-316 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 bamer . 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,345' 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 2048 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 25 -Jan -18 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 drillina a well Dennited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ❑ FIT Records w/LOT Graph p Surf. Casing Cementing Data 12 Other 21 Previous authorization for new product cleanup fluids for CD1 and CD2 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. L' �� A N -F (.�i^1 Signature: / i� Title: /"�-c^F cR Printed Phone Name: Chip Alvord Number: 265-6120 Date: r Commission Use Only Conditions of approval: 7 LOT review and approval: 01 )/Z 7D11C Subsequent form required: 10 — 11I- 2"S Approval 1� O (ipp✓ 11�i �nnumber: iRMM APYS �, 1� I•_� L 0 ���U Approved by, -"'� E TH C MMISSION Date: llrS tile; RZ1a pmt Rev _ I . I - I- m, m un mafn ,llN f�3 r V3 it do .ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 17, 2017 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-18 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-18 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 CD5-18 approximately January 25, 2018 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 CD4 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within ''A mile radius at AOGCC: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CDS-10, CD5-11, CD5-12, CD5-17, CD5-19, CD5-20, CD5-21, CD5- 22, CD5-99, CD5-313, CD5-314X, CD5-315, CD5-316. 12. Information regarding remaining wells within'/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 (16.2 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (18.0 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 more than 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, ��� Nina Ande on Yv Drilling Engineer cc: CD5-18 Well File Chip Alvord ATO -1570 Annulus Disposal Transmittal Form - Well CD5-18 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD5-18 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. 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/l. (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 pumped 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 drillingicompletion 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 2048 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 5650' 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 CD5-25, CD5-24 will be generated. 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. Well CD5-18 Date 1/17/2018 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) String Assumptions Surface Casing String in Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at thel0 3/4" 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 c Maximum Fluid Density to avoid v Pb29—t85% — PHydrostatic + PApplied - PFonx 4,4 = ( 2,188 * 0.052 ' M w,om ,,J 0 �f r MW.., = 34.1 ppg Ve 3.04.18 )+ 1500 - ( 0.4337 * 2,188 ) 3.5 "Tubing 7,634 TVD or 2,048 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pmllapse85% — PHydrostatic + PApplied - PGasGradient - PHeader 4,072 = ( 7,U93 . 0.02 Ivl W ooa ) + 1,50U - ( 0.07UU ` 7,093) - 1,000 M[w .m = 11 ppg 2nd Casing String 2,188 TVD Surface Casing String in Weight 29.7 ppf Size 10.75 in L 80 v TOC Est. @ 5,650' MD Weight 45.5 ppf Pcollapse85% 4,072 psi 3,795' TVI Grade LSO ft Gas Gradient a Stage Collar @ 6350' MD Pbu<au00% 5,210 psi PbM185% 4,429 psi Depth of Shoe 2,188 ft 1,500 psi Header Press 1,000 psi FIT/LOT @ Shoe 18 ppg - FIT/LOT for Annulus 16.2 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 12,796' MD 7,093' TVD 3.5 "Tubing 7,634 TVD or 2,048 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pmllapse85% — PHydrostatic + PApplied - PGasGradient - PHeader 4,072 = ( 7,U93 . 0.02 Ivl W ooa ) + 1,50U - ( 0.07UU ` 7,093) - 1,000 M[w .m = 11 ppg 2nd Casing String Size 7.625 in Weight 29.7 ppf Grade L 80 Pcollepsel00% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 7,093 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 Paaaallowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,188 *.052* 18 ) Pmax allowable = 2,048 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". 9:55, January 04 2018 CD5-1 8 Rama TVD shape C05-19 St C59 2197,69 Circle (Radius, 1920.90 Quarter Mile View Gpy i2 Gpy.03 Gp5'Oy Gpy Gpy.OtiP Gpy.12 Gp5.0� Gpy 0� Gpy.1'� --------------- Gph 1400 -- CIO Gpy.10 700 _ ........ I ; 0 n - - 00 Gpy 0 w � -700 G _ 0 Z 0�1 O � Gpy � L 01400 - -- - - - -- 9 -2100 Gpy � CD ' "CD5.314X _ Gp py „0 5-315 Gp5.313 py, ' GDG G -2800 -2100 -1400 -700 0 700 1400 2100 12800cpyyo GpS�° 2390.93 Total Centralizers = 15 Centeks , 42 Bows rin s 2390.93 2390.93 Centek SII, 10-3l4- x 13-1/2", PN 1034-1312S 2390.93 TOP -CO, Bow S rin , 10-314" x 17.085", Model 300-273 434 2390.93 2390.93 Remarks:Up Wt K t Use Seal Guard ECF on HYD 563 p: K MU Tq with Volant -15.2 k tNbs lr for Hyd 563 and 19.4K fNbs on dopeless Block Wt 60 K As Bakerlocked to pin and of #4 Driffted with 9.885" drift Rfg Supervisors: k HardinglA. Manrshack (! Cement ConocoPhillips CD5-18 Surface Casing Cement Cement Detalis--: - - Cementing Stert Date Cementing End Dare Wellbore Name Description 121x/2016 00:35 12I4I2016 03:28 CD5-10 Surface Casing Cement Comment Cemented With full returns. 183 We good cement to surface. .... Cer)IBht Stages - :., ... .. ... .. ... .:.. .,,;.. Stage#1:... U.--p—Top Top Depth(WO) .... Bottom Depth (RKB) Full Return? Vol Cement.. Top Plug? Bottom Plug? Yes Yes 38.5 2,390.9 Yes 183.0 Surface Casing Cement Pump InH (bblfmin) Q Pump Final {bbl/... O Pump Avg (bbg... P Rotated? fpe RPM (rpm) P Pump Final (psi) P Plug Dump (pat) Recip? Stroke (R) 0.00 NO D 8 3 6 450.0 1,020.0 Yes Tag Method Depth Plug Drllied Out To (RKB) Drill Out Diameter (in) Tagged Depth (ftKB) Ta Comment Cement Fluids & Additive. Fluid Fluid Type Fluid Dscriptl R Estimated TOP IRKB) Volume Pumped (bbl Est Bun Eet Btm (RKB) Amount Class 318.0 934 LIIeCRETE Lead Cement Mix H2O Ratio(gal/sack) Free Water (%) 36.5 1,891.4 Plastic Wscosity (Pa•0. Thiekent--Time (h0 Cmprstr1 (psi) 50.0 Yield(felsack) 0.00 11.00 220.0 5.50 1.91 6.79 _ . _ Additives"Concentration Cone Unit label Additive Type 0.2 %BWOC D046 Concentration Cone Unit label Additive Type 0.5 %BWOC D167 Concentration Cone Unit label Additive Type 0.06 gal/sx D185 ... ..: .. ;.;; 'i; ';: 'Vdume Fluid":;; Fluid Type Fluid Description Estimated Top (RKB) Est Bim (f(KB) Amount(sacks) pumped bM:. Gass p ( 57.9 Tail Cement Mix H2O Ratio (gal/sack) Fre, Water (Y) 1,891.0 2,391.0 240 Density (IblgaO Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 280.0 Yield (K'/sack) 0.00 15.80 102.0 5.00 _.:__ 1.16 5.09 "' Concentration Cone Unit label Additive Type 0.2 vkBWOC D046 CancentraGon Conc Unitlabel Additive Type 0.3 %BWOC D065 Concentration Conc Unitlabel Additive TYPa 0.4 %BWOC D167 Page 1I1 ReportPrinted: 1211812017 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD5-18 Rig: Doyon 19 Date: 12/5/2016 Volume Input strokes Volume/Stroke 0.10001 Bbls/s k Pump Rate: Drilling Supervisor: K. Harding /A. MarushackPump used: #2 Mud Pump i '11Type of Test: Casing Shoe Test LOT/FIT 'V Pumping down annulus and DP. qw 0.50 Bbl/min asmg Test I Pressure Integrity Test Hole Size: 9-7/8^ Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB H 36.7 Ft 2391.0 Ft-MD 2188.0 Ft-TVD I 2420.0 Ft-MD 12209.0 Ft-TVD Strks psi Min I psi Strks psi Min psi Casing Size and Description: 10-3/4° 45.5#/Ft L-80 BTC V I 1 0 70 0 3600 2 60 0.00 960 Casing Test Pressure IntegritVTest 2 140 1 3600 4 120 0.25 960 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg Mud 10 min Gel: 8.0 Lb/100 Ft2 Mud 10 min Gel: 7.0 Lb/100 Ft2 Test Pressure: 3500.0 psi Rotating Weight'l 12000.0 Lbs Rotating Weight: ###### Lbs Blocks/Top Drive Weight: 60000.0 Lbs Blocks/Top Drive Weight 60000.0 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 2.7 bbls Estimates for Test: 956 psi 0.9_bbls WL 'w tMW = ea-off-P-ressure + Mud-W-eight 960 + 9.6 PIT 15 Second 0.052 x TVD 0.052 x 2188 Shut-in Pressure, psi EMW at 2391 Ft-MD (2188 Ft-TVD) = 18.0 ppg 1 960 4 350 -6-560 2 3590 6 340 0.50 960 -3-3759-0 8 520 1.00 955 8 830 4 3590 10 700 1.50 955 10 1000 5 3590 12 850 2.00 955 121 1150 6 3580 13 960 2.50 954 14 1250 7 3580 3.00 950 16 1380 8 3580 3.50 945 18 1540 9 3580 4.00 945 20 1710 10 3570 4.50 940 22 1900 15 3570 5.00 938 4000 4 Lost 50 psi during test, L a 24 20801 20 3560 5.50 935 26 2320 25 3560 6.00 930 3500 28 2490 30 35501 6.50 928 30 2690 7.00 925 32 2920 7.50 920 3000 34 3140 8.00 915 2500 36 3360 8.50 910 LU 38 3600 9.00 903 9.50 900 rn 2000 to 10.00 895 LU a1500 1000 EX 500 0 i- 0 5 10 15 20 25 30 Shut-In time, Minutes o PITPoint 0 1 2 3 Barrels .-CASING TEST --N-- LEAK-OFF TEST Volume Pumped Volume Bled Back Volume Pumped Volume Bled Back S S S S Comments: Casing test with 9.8 Drilplex FIT with 9.6 LSND Summary Time Log & Summary Report [AOGCC] A CDS-18 Well Name: CD5-18 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 1211/2016 Rig Release :112112017 Time Log - .5mnTYna .End Time:.. bur tnd Siad bpN, End beW,r Plgve bP Cdde AeONry'Cdde TYr-x -T-X P : bnepa . Pumped 34 bbl NP sweep and BROOH f12,400' 1213/2016 00:00 12/312016 04:15 4.25 2,400.0 1,675.0 SURFAC CASING BKRM to 1,675' MD with 800-700 gpm, 2540-2040 psi, 60 rpm, and 3k To. Saw consistent hole unloading and had to reduce rate to reduce losses over the shakers. BID TD and look P/U= 130k, SIO=115k. 1213/201804:15 12/3120160430 0.25 1,675.0 1,675,0 SURFAC CASING -(5W--F-F— P OWFf, Well static. 12/3!201604:30 12131201605:45 1.25 1,675.0 831.0 SURFAC CASING TRIP P 800500'11.676'o 831-M. Observd 225` ands OD MD with e35k hl spots overpull. 1213/201605:45 12131201606:00 0.25 831.0 831.0 SURFAC CASING OWFF P OWFF, Well static. 1213/2018 06:00 12/312018 08:15 2.25 831.0 0.0 '§u—RF—Ac S CASING BHAH P R/0 5 stands HWDP jars, nd NMDCSLB. Total trip calculated fill = 21 A bbl, actual = 31 bbl 12x3/2016 0815 12!312016100 1.75 0.0 0.0 SURFING CASING RURD P R/U Volant and 10 3/4' casing running tools. Clear BHA handling tools from floor and UD. Monitored well on TT with 11.5 bbl losses in 3 hrs. 1213/2016 10:00 1213/2016 16:30 6.50 0.0 1,461.0 SURFAC CASING PUTO P check floats and RIHto 1H,74MAJ 10 87 MD d 563 hoe per r ck, Had to wash through light spots at 850' and 1,380' MD with 3 bpm, 130/240 psi. . T2—/3/201616 30 12/3120161715 0.75 1,461.0 1,461.0 SURFAC CASING CIRC P Circulatedmps up to6 pm with 340 psi.conditioned PIUa 140k 00. 12/3/2016 1715 121312016 —Ig 15 2.011 1,461.0 2,352.0 SURFAC CASING PUTS P Continue RIH f/ 1,464' l0 2,391' MD with 10 314" casing. 1213120181915 12/3/20162000 0.75 2,352.0 2,391.0 SURFAC CASING HOSO P 9thaDger and landing joint and land casing at 2 1213/2016 20:00 12/3/2016 23:00 3.00 2,391.0 2,391.0 SURFAC CEMENT CIRC P Circulate and condition mud for cement jo6. staged pumps up l0 8 bpm with 200 psi. Dropped YP in 10 ppg mud to 18 op. 1213/2016 2300 T21312016-23 :30 0.50 2,391.0 2,391.0 SURFAC CEMENT RURD P B/D TD and cement hose to swivel. Close IBOP and manual valves. 12!312016 23:30 12/4/2016 0:0 0.50 2,391.0 2,381.0 SURFAC CEMENT CIRC P m. PA)=150k, S/O==ulate and 125k. Sim -Ops, ition �mud at 8 Held Cement Pre -.lob with crew coming on tour. Page 1/1 Report Printed: 1 211812017 n, •_� - Time Log & Summary Report [AOGCC] r ' l CD548 Well Name: CDS-18 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept :1211/2016 Rig Release: 1/21/2017 `. oer smrtoegn Em Mp1h tiKa) ph -336'. -Op Code AcGviry Cade -T% 'SIanlYne ii 12/412018 00.00 End Tme 1214201600:15 0.25 2,391.0 2,391.0 BUREAU CEMENT CIRC P and at 8 bpm, 490 gpm, condition mud PIN=1150k, 8/0= 126k. 12/42018 00:15 1214/2016 WAS 3.50 2,391.0 2,391.0 SURFAC CEMENT CMNT P mp 75,2 bis 10 5 pell PT 1pg Mud Push ines to27)0 1144.2 pm, Dowell u @ 350 psi, Drop btm plug, Dowell pump 40.2 bbi of 119 scavenger cmt Followed by 278.5 bbls 11.0 ppg (935 sks -1.91 yld LlleCrele total) lead cement W/5 bpm @ 350 psi, Dowell pump 57 bbls 15.8 ppg (240 sks -1.17 yid Class G) 15.8 ppg tall cement w/3.6 bpm @ 420 psi, Drop top plug, Dowell pump 20 bbis water, 5 bpm, 560 psi, Rig chase with 202 bbls 10.0 ppg DrilPlex mud w/8 bpm @ 790 psi, slow to 3 bpm @ 450 psi last 10 bbls, and bump on schedule with 2008 stks @ 95.8% eR. Pressure up to 1020 psi & hold for 5 min. Check floats (good) CIP @ 03:26 his. Reciprocate pipe w/full returns. 183 bbls good cement to surface. 12(4/2016 03:45 1214/2018 04:00 0.25 2,391.0 2,391.0 SURFAC CEMENT CIRC P bpmhalnd 400 psi. Pumped al total f 70 bbl cd functioned annular 3 times before shutting in on landing joint. 12141207604:00 -i-21-41201605 30 1.50 2,391.0 0.0 SURFAC CEMENT WOC P cement lines. B/D TO, cement, volo�t, casing land mud linnees. UD 10' pup on landing joint while WOC. 1214/2016 05:30 12/4!2016 08:30 3.00 0.0 0.0 SURFAC CEMENT WOC P Changed out encodedrawr on DrksW. WOC. 12/412018 08:30 12142016 10:00 1.50 0.0 0.0 SURFAC CEMENT WOC P B/HA and crack back while WOC ediate drilling -,4/2o,61 1214/201011:15 1.25 0.0 0.0 SURFAC CEMENT WOC P Clean pits while WOC. performed PM2 work on T2 o oo 1214/201611:15 12/41201613:15 2.00 0.0 0.0 SU CEMENT WOC P PN and RIB 15 stands of 5" NC50 DP 1214!201613:15 12141201614:30 1.25 0.0 0.0 SURFAC CEMENT WOC P Slip &cut 53' of drill line. SIMUS M/t110' pup to 1214/2016 14:30 12/412018 15:15 0.75 0.0 0.0 SURFAC CEMENT WOC P landing � joint and clearilOer. -r-- 15:15 1essure 214/2016 16:30 1.25 0.0 0.0 SURFAC CEMENT OWI -1- P Iscume) and open. Instack,ulmonawwell and rinse riser. Function annular (no cmt contamination). 12!4201617:15 0.75 0.0 0.0 SURFAC CEMENT RURD P joint and mouse hde. BID hole fill 1214/201616:30 lines, 1.25 0.0 0.0 SURFAC CEMENT NUND P NNIIDrflow line, hot. fill, Bleeders, and UD surface 1214!2016 1715 12/4/20161830 12/42016 18:30 1214/2016 21:00 2.50 0.0 0.0 SURFAC CEMENT NUND P NID startng'l a ge annular and set on skid. NID 12/42016 21:00 12!52016 00:00 3.00 0.0 0.0 SURFAC WHDBOP NUND P N100 psl fon a d ROPE. Test casing hanger to ua r �n Report Printed: 121181201-1 9 CD5-18 7-518"Intermediafe casingI. tL- D5.10 2 7 518" 29.7# LBO BTC -M & ffyd 563 Dopeless Casing ate- 125-71110F16 Rig: DDyon19 ConocoPhillips Alaska, Irka, Depth Jt Number Well Equipment Description and Comments Length Tops Page 1 to Lock Down Screws 34.15 FMC 7.625" fluted hanger tz 7-518", 29.7#, L-80 PUP in x in be low hanger H563 2.31 37.87 its 320 to 37 so -its Y--5/8-,29.7#, L-80 H563 Dopeless Casing 2404.08 718 244126 7-518", 29.7#, L80 XO it, H563 DPLS box X BTG in 0 its 223 to 319 7-5/8", 29.7#1 LBO, BTC -M Casi I -- 3 8 .36 2481.78 63511.14 n kto 83�, jar (Qannfk base f4,da nj 3.07 its 36 to 222 187 its 7-5/8". 29.7#, LBO BTC -M Casin 7482.67 1 3835.86 7-618", 29.7#, L-80 BTC -M Pup Joint 6 - 7-518", 29.7#, L-80 BTC -M Pup Joint 7.68 13TJ 44.54 Jts 35 to 35 1 its 7-618", 29.7#, LBO, BTC -M Casing with RA Tan in Coupli lin 41.10 13652.22 its 33 to 34 2 its 7-5/8", 29.7# L-80 - B-T-I&M-Casin IsIng, q FS psing 80.31 40.25 13893.32 13973.63 its 3210 32 1 its I 1074.69 14013.88 its 5 to 31 27 its 7-5/8", ZU-tt L-80 B TC -M Casi-- 7-518" HES Baffle Collar 1.23 15088.57 its 3 to 4 2 its 7-5ff', ZV I -BO BTC -M Gas,'-- 81.61 15089.80 15171.41 7.518" HES Float Collar 1.24 5.74 72.62 15172.65 its I to 2 2 its 7-5/6", 29. 7#, LBO, BTC -M Casing 15248.39 7-618" HES Eccentric Nose shoe 15251.01 Alpine C Top 13,982' MD / 7,500' TVD 15251.01 TD 9-7/B" Hole at 15.263- MD / 7,633.7' ND (11" 15251.01 Casing Shoe at 15.251' MD 17,7634.5' TVD 86.079 Inc 15251.01 152 1.01 1 Hydroform 10' up from shoe w1sto,p ring on Jt #1 .... .. '15N 1.01 Jt 02 1 Centek 30' up from shoe wistop ring on J 15251.011 3 Centeks per 2 joints from #3 - #29, stops at 27', 13' as per schedule. 15251.01 I I Centek on its #3D and #31 below stop ring 5' from pin 15251.0'1 NW4@MlfC t#g4,�and U - - - - - - - M 15251.0', 3 Cen e s per 2 joints from #33- #61, s tops at 27', 13' as per schedule. I 1 Centek per joint floating from #222- #239 15251.01 I Centek on every joint #320 4322 15251.011 1 Straight Biade Centralizer on every other int from #324.- #37 8 15251.01 _31.11 - Tufai e"WIS-K(cimb tralij ht )iCades 28 15251-01 1-y�d-ofo:?k 15251.01 Remarks: Up Wt NIA K Baker Lock shoe track to pin of joint #6 DnWt 150 K Baker Lack stage collar & pin of joint #222 Block Wt 60 K MIU Tq for 7-5/9' HYD563 DPLS 12,400 ft/lbs Avg. M/U Tq fOL7[-510'-' BT ,clmw ww, vv olant = 10,400 f Vlbs Rig Supervisors: R. Bjorhus R. Reinhardt a r e length Tops Jt Number Joints well cguipn leu, uea+.„r•,....... _...... ..... Page 2 15251.01 15251.01 Extra BTCM Jts Outside = 29 15251.01 1 float collar A out 15251.01 15251.01 Extra XO outside = 34.10 15251.01 15251.01 Pups BTCM 15251.01 20.20 15251.01 8.66 15251.01 7.68 15251.01 5.66 15251.01 15251.01 15251.01 Pups Hyd 563 15251.01 19.85 15251.01 9.84 15251.07 5.93 15251.01 4.88 15251.01 3.93 15251.01 15251.01 Centralizers 1 H droform Tesco 480703 7-5/8 x 9-3/8 108 Centeks, SII #0758-0978S, 7-5/8" x 9-7/8" 28 Ra Oil Tool, #4830-9S, 7-5/8" x 9-5/8" x 8" 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 15251.01 Remarks: Rig Supervisors: R. Bjorhus / R. Reinhardt Page 1'. Cement Conot.oPhillips CD5-18 Intermediate Casing Cement Cement Details ` -Cementing startDale Cementing End Date Welll bore erne Description 12/16!20182245 12!171201605:30 CD5-18 Intermediate Casing Cement Comment Cemented two stage job with Poll returns. 40 bbl Mud Push ahead of each stage. Cement stages.. ..:...::. Ste 6#1. :.:- ., .. -- :. :_ :.:..... Top Depth (ftKB) go nn Depth IRKS) Full Return? Vol Cement... Top Plug? Bottom ug Yes Dascrip_ Intermediate llon Objective Casing Cement Intermediate, 12,796.0 152500 Yes Yes Cement 500' above KUp C Rotated? Pipe RPM (rpm) Avg (bbl(... P Pump Final (psi) P Plug Bump (pal) Reeip? Stroka( I Q Pump Inst (bb0min) Q Pump Final (bbv... Q Pump No 4 8 7 750.0 1,300.0 No Depth Plug Drilled Out To IRKS) Drill Out Diameter (In) Tagged Depth (ftKB) Tag Method 63/4 Drill Bit Comment Cement Fluids &Additives- :.Volume Fluid Class Pumped (bbl):. Fluid Description Estimated Top (ftKB) Est Blm (ftKB) Amounl(sacks) 215.7 Fluid Type 1 036 Cl Intermediate Cement 12796.0 15,263.0 Denai IW al Plaetle Viseoslty (Pa•s) Thkkening Time (hr) Cmprstrl (psi) hr ( 1 Yield (il'lsack) Mix M20 Ratio (gagsack) Free Water (%) 9 15 � 128.01 6.00 1.16 S.D7 Additives.-. -' Concentration Cone Unit label Additive Type 0.2 %BWOC Antifoam 0046 Concentration one Unit label Additive Type 0.3 %BWCC Dispersant 0065 Concentration one Unit label Additive Type 0.4 %BWOC Fluid Loss Control 0167 Concentration no Unit label Additive Dt77 0.02 gallsx .: ... Retarder .. Stage # 2 .. :. Top Depth (ftKB) Bottom Depth (ftKB Full Return? Vol Cement... Top Plug? Bottom Plug? No O Description bjective Intermediate Casing Isolate Cannik, 500' 6,651-.0 6,350.0 Yes Yes Cement aboveRotated? Pipe RPM (rpmj Q Pump Init (bbilmin) Q Pump Final (bbg... Q Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) No 3 8 7 360.0 1,500.0 No Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Tagged Depth (ftKB) Tag Method 8 314 Drill Bit Comment Cement Fluids 8 Additives , .. Fluid... - - -- '-"' ""' ''Amaunt(saeke Class Volume PumPed(bbg Fluid Description Estimated Top (ftKB) Est etm(f1KBI ) 57.6 Fluid Type 276 G Intermediate Cement 5,650.0 6 350 0 Density (Ibfgal) Plastic Viscosity (Pa•s) Thbkening Time (hr� CmprStr 1 (psI) Yield (fP/sack) MIx H2O Rano (gaVsaek) Free Water (Y.) 75 15.801 43.0 11.16 5.09 Additives ... • :::..... Typ,.. - :: - - - - '" -: Concentration Cone Unit libel Additive a 0.2 %BWOC Antifoam D046 Concentration Conc Unit label Additive 0.3 %BWOC D065 Dispersant D06Concentration Conc Unitiabel Additive 0.4 %BWOC Fluid Loss Control D787 Raoort Printed: 1211612017 Page 1'. Well Name: I CD5-18 I Rig: Drilling Supervisor: I Rick Bjorhus Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: »" ♦ Casing Shoe RKB-CHFJj 36.7 Ft I 2391.QjFt-MDj 2 Casino Size and Description: USE PICK LIST Chanoes for Annular Adequacy Test Enter outer casing shoe test results in comments Casing description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. 1000 w U) 500 W W O' a o■ 0 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 12/17/2016 Volume Input Pump Used: Other - See Comments —.-- Barrels ♦ Pumping down annulus. IV asu 1 Hole Depth Pumoina Inner casing CID: I 10.011n. Desired PIT EMW: Estimates for Test: '_L a ressure + u eig = 590 0.052 x TVD 0� + 11 EMW at 2391 Ft -MD (2188 Ft -TVD) = 16.2 r. PPg psi -0.3 bbl. Shut-in Pres 223 2 4 6 8 10 12 14 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes CASING TEST BLEAK -OFF TEST o PIT Point sed #2 Injection Pump in Ball mill T for Surface casing shoe was 18ppg Bbls/Strk Lt Shut-in P' 3.2 ON=I= mp Rate: Bbl/min egnty est Shut -In Summary 1 1 1 Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD5-18 IRig: Doyon 19 Date: 12/20/2016 Volume input Volume/Stroke 0.1008 Bbls/Strk 'W7.00 Pump Rate: Drilling Supervisor: R. Bjorhus, R. Reinhardt Pump used: uz Mud Pump IV strokes 1w strk/min Type of Test: Casing Shoe Test LOT/FIT 'W 1 Pumping down annulus and DP. IVasing Test ressure Integrity Test Hole Size: 6-3/4" Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 34.2 t I 15251.0 Ft -MD 7633.4 Ft -TVD I 15283.0 F_t-MD 7635.0 Ft -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 7-5/8" 29.7s/Ft L-80 BTC -MOD w 0 0 0 3575 1 10 0.00 834 Casino Test PreSSurelntearitVTest 4 300 3550 2 20 0.25 800 Mud Weig t: 10.7 ppg Mud 10 min Gel: 11.0 Lb/100 F11:2 Test Pressure: 3500.0 psi Rotating Weight: Lbs Blocks/Top Drive Weight 60.0 Lbs Estimates for Test: 8 bbis Mud Weight: Mud 10 min Gel: Rotating Weight: Blocks/Top Drive Weight: Desired PIT EMW: Estimates for Test: 10.4 ppg 11.0 Lb/100 Ft2 155.0 Lbs 60.0 Lbs 12.5 ppg 834 psi 2.2 bbls 8 550 -2-375-2-5 3 40 0.50 790 12 750 3 3525 4 8 1.00 780 16 950 4 3525 5 140 1.50 780 20 1100 5 3525 6 180 2.00 780 24 1300 6 35201 7 230 2.5 780 28 1500 7 352 -8-260 3.00 780 'w I I w 32 1700 8 3520 9 290 3.50 775 LMVw = ea -o ressure+ u eight = 834 + 10.4 0.052 x TVD 62 EMW at 15251 Ft -MD (7633.39 Ft -TVD) = 12.5 ppg PIT 5 Second Shut-in Pressure, psi 36 1850 9 3520 -10-330 4.0 770 40 2025 10 3520 11 370 4.50 770 800 44 2225 15 3520 12 410 5.00 765 4000 3500 3000 w 2500 0 2000 LU w a1500 Lost 55 psi during test, Id cl 1r;0A Af to t 481 2450 20 3520 131 4601 5.50 760 52 2650 25 3520 14 500 6.00 760 56 285030 3520 15 540 6.50 760 60 3025 16 580 7.00 760 64 3225 17 620 7.50 755 68 3450 18 660 8.00 750 71 3575 19 710 8.50 750 20 760 9.00 750 21 800 9.50 750 22 834 10.00 740 23 24 1000 500 °30 0 1 z a 4 s s 7 a o s 10 15 20 25 30 Barrels Shut -In time, Minutes CASING TEST -1111 -OFF TEST o PIT Point 25 26 27 28 29 1 Volume Pum ed Volume Bled Back Volume Pum eci Volume Bled Back S S S S Comments: FIT to 12.5EMW Summary nx Time Log & Summary Report [AOGCC] CDS-18 Well Name: CD5-18 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 12/1/2016 Rig Release: 1/21/2017 Time Log ..fT2-1-14/2016 p� r: r. elaei DepN nd EM De N a PfiSe OPCode AoMdyCoEe nMop T-kgout .'. we--: 3,334.0 2,329.0 INTRMI CASING BKRM T of hole 3.33V to12/14/2018 2�g MD 3.75 Q 8x00 gpm, 301 D-2920(psi. 10 rpm, 00:00 4k Tq. Observing large clay retums. Slow rotary as stabs and bit enter casing shoe. Observed slight packo8s (30 psi) with bit 25' from shoe. 12114120188 0.50 2,329.0 2,329.0 INTRMI CASING CIRC T Estapm, 2.5.3kish rTq. Pump 35 bbl HVVHDNPpm. 2920 t sweep 03:45 04:15 12.5 ppg around followed by another bottoms up. Good Gay returns throughout and after sweep, shakers cleaned up. 12/141016 12/1412016 0.25 2,329.0 2,329.0 INTRMI CASING OWFF T Observe well for flow, static and dropping 04:15 12/14/2016 04:30 12-114/2016 1.75 2,329.0 -Pump 823.0 INTRMI CASING PMPO T HWDP), 500 gpm0 0 psi. OWFF static, 04:30 0:15 PJSM on W BHA. 12114/2016 121142016 1.00 823.0 272.0 INTRMI CASING PMPO T ont823, M0 to 272' MD BHA. mpng gpm 980 psi from Continue 06:15 07:1542 0.0 INTRM1 CASING SHAH T on trip tank, IaTdown l,, Fill 12/1412018 12/1412016 1.75 272.0 DO, Total trip Cale fill 13 bblPOCH Actual 344 07:15 09:00 bbl. , 12/14/2016 1211412016 1.25 0.0 0.0 INTRMI CASING WWWH P stlack washeean and r and flush stack with 600-700 1 pm, 09:00 10:15 340380 psi. 20 rpm, .5k Tq. Lay down stack washer, drain stack and pull wear ring. 12114/2016 12!142016 0.75 0.0 0.0 INTRMI CASING BOPE P SIMOChanPS-= RIU Volant CRT, pick ulp ball 10:15 11:D0 extensions via beaverslide 0.0 0.0 INTRMI CASING BOPE P Set 7-5181 test ac ater. Test I s6 12114/2016 12/142016 1.00 annular l0250 50, min each. 11:00 12:00 0.0 INTRMI CASING ROPE P /equipment250/3500 psi 5 min each. 121142016 12/1412018 0.25 0.0 WD testlast 12:D0 12:15 0.0 0.0 INTRM1 CASING BOPE P Jointset thin wall wear ring per FMC 12/142016 1211412016 0.50 rep 10t 12:15 12:45 0.0 INTRMI CASING RURD. D P -_ JU bail eMensions, 350 ton 12114/2016 121142016 0.75 0.0 Rlips casing elevalorst. 12:45 13:30 3,859.0 INTRMt CASING PUTS P BTCM casing. Made ?baf�ec 12I14I2016 121152016 10:5 0.0 up shoe, float collarUand collar 13:30 00:00 0 and BLioints, establish circulation and checked floats OK. Continue running casing to 3,859' MD, torquing BTCM connections @ 10.4k to the mark. SIO=120k 0 3,859. Page 1N ReportPrinted: 12/1812017 ary-�s Time Log & Summary Report [AOGCC] 3 G � n CD5-18 Well Name: CD5-18 Rig Name: DOYON 19 • Job type: DRILLING ORIGINAL Rig Accept: 121112016 Rig Release : 1/21/2017 -;, '.. Time Log Dur M) _ .at uep�h - jflK1) EngDo (N2B1 _:. ppasa !.. Cpcode .-. Adlvily Cade M.P T-x operation -'s�artLma Erd Time'" 12115/2016 3.75 3,859.0 6,341.0 INTRM1 CASING PUTB P casing from 3,859 MD to 6,341LMD Bo quing 1211512016 00:00 03:45 BTCM connections @ 10.41k to the mark. P/U=180k, S/0=145k pumping .5 bpm. 12/15/2016 1211512016 2.00 6,341.0 6,341.0 INTRMI CASING CIRC P E tab5 bpm1,s220-260 at On Cirrculatee1 bottoms up while 03:45 05:45 reciprocating pipe 3400 stks. Heaviest mud returns observed 11.1+ppg. 12/15/2016 fi28 6,341.0 9,419.0 INTRMI CASING PUTS P TCM casic�nng from 6,3417MD to 9,41!9' MDgtoquing 12/15!2016 05:45 1200 BTCM connections @ 10.4k to the mark. Made up stage collar @ 8,900' MD, Baked-ock'd and torqued to 11.8k. Verified six shear screws installed. S/0=1 62k @ 9,419' MD. 12115/2016 12/15/2016 225 9,419.0 10,096.0 INTRMI P 0 BTCM from 9,4 junjilliV MD to 10,096 aMD, torquing 12:00 14:15 casing BTCM connections @ 10.4k to the mark. 4TB PIU=275k, S10=165k. 12!1512016 3.25 10,096.0 10,137.0 INTRM1 RC P stage up from 5 bpm to Estab5 bpm, s290-390 psi. Circulate ula e I bottoms up while 12/15/2016 14:15 17:30 reciprocating pipe 6580 stks. P/U=275-250k, S/0=165-160k. Heaviest mud returns observed 112+ppg 12/1512016 12/16/2016 6.50 10,137.0 12,173.0 INTRMI CASING PUTB P inue unri1 CTCv from 10n 37' MD to 1? 173' MD, torquing 17:30 00:00 casing BTCM connections - 10.4k to the mark. 510=175k @ 12,173' MD. Page' 111 Report Printed: 12!1812017 Time Log & Summary Report [AOGCC] GD5-18 ` Well Name: CD5-18 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 121112016 Rig Release :112112017 Time Log Dur Start Oeph, :(Itka) '..:.. End DOW, ._. .phime Op Coda e IimePT -TX6!2016 P 12/16/2018 1.50 12,173.0 92,567.0 INTRMI CASING �m Nom 12"93'MD to 12,567MD, torquing 00:00 01:30 STCM connections @ 10.4k to the mark. rTCi—Rc S10=182k @ 12,567' MD. 1217812018 12116/2016 4.50 12,567.0 12,567.0 INTRMI CASING P m to 4 350-490lPSI. Circulate lon and eIubottom$ Upp from .5 pWhile 01:30 06:00 pmt, reciprocating pipe 7800 elks. PAI=310-290k, S/0=1 75k. Heaviest mud returns observed 11.3 PPg- /2016 12/16/2016 8.00 12,567.0 14,550.0 INTRMI P Continue running 7-5I 29.7# L-80 BTGM casing from 12,567' MD to 12,809' MD, P/U XO 12:00 Jt to H563, continue running Hydril 563 to 14,550'MD torquing H563 dopeless connections [1211612016 FCASUNIGPUTB @ 12.4k. S/0=150k @ 14,550'MD. 1211612016 2.75 14,550.0 15,215.0 INTRMI PUTS P from 14,550' MD a 15 215' MD, torquing ng H5630 H563 g 14:45 dopeless connections @ 12.4k. S/0=150k @ 15,215' MD. 12-/1612016 12/16/1016 025 15,215.0 75,251.0 INTRMI CASING HOSO P joint, ack off and land hangerr@15,251hanger and aMD.g 14:45 15:00 12/16/2016 12116/2016 6.50 15,251.0 15,251.0 INTRMI CEMENT CIRC P Establish 0-600 circulation and stage up from t bpm to 8 pm, 0 psi, max mud weight out 1.3 15:00 21:30 l to ppg, stage up to 8 bpm as mud weight fell to tie up 11.0 ppg. Cirmlate 2.5 bottoms up conditioning mud for cementjob per program. 12/16/2016 0.50 15,251.0 15,251.0 INTRMI CEMENT RURD P auto and man! al 160P. RIU cement i eriveto lose Shut down, and blow down top12!16/2016 21:30 22:00 Volant CRT. 12/16/2016 1016 2/16/2 0.50 15,251.0 15,251.0 INTRMI CEMENT CIRC P �naebnifhrcerculation @ 8 bpm 600 psi via 22:00 22:30 SIMOPS- PJSM on cement job. 12/16/2016 12116/2016 0.25 15,251.0 15,251.0 INTRMI CEMENT OWFF P Shutdown and observe well forgoes, static l0 22:30 1211812016 22:45 1211712016 1.25 15,251.0 16,251.0 INTRMI CEMENT CMNT P esti to 4000 psl- gSLB flood lines lh 2 bbl mater and pressure ood. Bleed off pressure. SLB 22:45 00:00 spacer. Shut down ndload bottom ypa s) plug. B mix and begin pumping 15.8 ppg Class G Qannik Slurry @ 4 bpm, too psi SPP. 100 bbl pumped @ 24:00 hr with full returns. SID @ 54 bbl away due leaking Volant cup. Shut down and pulled to change cup, found piece of Buns rubber from bypass plug had caught between V013nt stabbing guide and cup, tearing off —40% of the top tin of the bypass plug. Retrieved the rubber, re -stab Volant and resumed cementing and displacement. Total pumps off time 4 minutes. Page 111 Report Printed: 1211812017 Time Log &Summary Report [AOGCC] e Il`- CD5-18 Well Name: CDS-18 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept :121112016 Rig Release: 112112017 - $,gi re :.: .. EM Time... Our aYa Oeplh a� Phesa Op Code Tnn➢.... 7idWdj Cade Y P .: sta )Class 12-117/2016 12117/2016 2.50 15,251.0 15,251.0 INTRM1 CEMENT CMNT p�Ped total 597 bbl of 15.8 ppg G 00:00 02:30 Qannik slurry @ 4 bpm, 110 psi SPP. Load and drop top plug, SLB kick out plug with 10.3 bbl H2O. Rig displace cement with 11.0 ppg LSND as8 bm, 320-1120 Psi. Slowed pm as plugs pass stage collara d prior to bu Bumped plug @ 6846 slks 750 psi. Pressure up to 1300 psi and hold 5 min. Bleed off and check floats - Good. 12/17/2016 1.25 15,251.0 6,350.0 INTRMI CEMENT CIRC P Pre6 350' MO per HES Psi. ep. CBU stage pumps up 12/1712016 02:30 0345 to 8 bpm 540 psi, maintain MW 11.0 ppg Inlout. SIMOPS- PJSM on sage 2 cement Job. Shut down, OWFF salic. 121172018 2.00 6,350.0 0.0 INTRMI CEMENT CMNT P DP9 MudPsh It 3.3 bpm SLB mm and 240 psump i Follow with 12/17/2016 03:45 05:45 57.6 bbl 15.8 ppg Class G Qannik slurry 3.1 bpm 135 psi. Shut down and load closing plug. SLB kicked out plug with 10 bbl H2O. Rig displaced cement with 11.0 ppg LSND @ 8 bpm, slowed to 3 bpm 370 psi to bump plug @ 2815 slits. Pressure up to 2000 psi, observe sage tool shift @ —1800 psi. Continue pressure up to 3300 psi and hold 5 minutes to ensure stage tool Is dosed. 12/17/2016 0.50 0.0 0.0 INTRMI CEMENT RURD P down landing joln4g down cement floes. Lay 12/17/2016 05:45 08:15 12/17/2016 1.25 0.0 0.0 INTRMI CEMENT W WSP P MIU packoff to runningyueai itool,iset packoff per FMC 12117/2016 06:15 07:30 rep. Test packoff to 5000 psi for 10 minutes CPAI witnessed. Lay down running tool. 12117/2016 12/17/2016 1.00 0.0 0.0 INTRMI CEMENT RURD P down yvi�a sl de. I spect lop drVolant riive, reT. move skate oiler. 07:30 08:30 0.0 0.0 INTRM1 CEMENT PULD P down 8 stands 5" DS50 ddll pipe via 90' 12/1712018 121172018 3.50 iLnnsehole. 08:30 12:00 SIMOPS- Change out Upper pipe rams from 7- 5/8" SBR to 3-1/Y x V' VBR. 121182016 12.0 0.0 -0 0 INTRMI CEMENT PULD Psdand 90 stands 5" NC50 Via 9f` mo seho e. 127172016 12:00 00:00 0 SIMOPS- GIS perform annular LOT (16.2 ppg), annular flush 300 bbi H2O 3 bpm 550 psi and freeze protect with 84 bbl diesel @ 2 bpm 653 ShI ut In annulus @ 20:00 hrs. OA pressure @ 22:00 hrs=700 psi. Page 111 Report Printed: 1 211 812 01 7 SURFACE CASING SHOE SEPARATION FROM CD5-18 planned CD5-18 planned x v Surface Casinq Shoe ASP 4 Coordinates NAD 27: 349542.44 5965128.75 Wells Details @ AOGCC Ann. Disp. Permh # Permit Date Source well Ann. Vol. '* Start Date u1stance from Object End Date well' Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surface Surf LOT casing TVD (ppg) (ft) Annular LOT (ppg) Annular LOT Repeat (ppg) Comments CD5-3 4 PB" Y 169 349548.80 96 40 . 14.8 CD5-04 Y 561 349856.86 5965593.81 14.8 2231 16.4 CDS-313 Y 268 349555.10 50653M25 17.3 2155 19.2 18,0 Not a candidate, Surface Wa er CD5-05 Y 1176 349773.14 596628177 15.9 2165 16.3 CDS-315 Y 261 349296.66 5965215.35 17.7 2159 16.10 14.20 CD5-03 I Y 315-762 1 10/12/2017 co5-10, co5-07, CD5-12, CD5-08, CD5-01, C05-17, CD5-314X, CD5- 316, CD5-22 49276.74 11/2/20151 1557 349510.01 5966685.74 17.2 2156 14.80 Permit extension to 70,000 Dale Extension to 10/12/18 CD&09 1550 349249.13 5966650.27 18.0 2168 18.00 14.80 CD5-11 Y 317-597 114/2018 CD5-02, CD5-06, CD5-99 21813 4/112016 978 349653.70 5966100.56 18.1 2169 16.30 n to 70,000 CD5-10 747 34984 .09 5 65809.89 15.2 2147 14.30 CD5-07 Y 977 349846.29 5966056.85 18.0 2190 16.80 CD6-01 Y 1404 350044.74 5966440.02 16.0 2178 17.70 CD5-02 Y 1523 349730.00 5966640.00 17.0 2189 16.60 kN,da 005-21 1332 $48881.27 5966144.79 18.0 2378. , o Int CasinCD5-08 Y 1091 349469.91 5966216.96 180 2187 1410 C05-12 Y 316-381 9/1/2016 C 5-20 12005 12/1/2016 1092 349560.00 5966220.97 18.0 2187 14.80 CD5-06 Y 1312 349534.51 5966440.23 18.0 2190 13.60 0105-99 Y 535 349969.59 5965450.67 18.0 21821 15.10 CD5-18 Y 0 34954244 5965128.75 18.0 2187 16.20 CD5- 0 1470 348934.93 596846 .80 17.5 2183 14.40 CD5-17 Y 542 349477.00 5965667.00 18.0 2181 15.70 CD5-314X Y 445 349111.00 5965237.00 18.1 2183 16.70 CD5-316 Y 699 348858.83 5965276.22 16.0 2175 CDS-19 Y 337 349286.33 598534725 18D 2187 15.20 CD5-22 Y 1058 349068.04 5966073.91 18.1 2184 16.40 CD5.23w 14 1117 348993.55 5966101.39 15.3 2178 In Pr cess of being drilled CD5-25w 15 i 651 349091.35 5965598.79 CD5-24w15 509 349186.31 5966474.52 ' Lateral distance in feel, between surface casing shoes, in the X -Y plane Note that this sheet is not the definitive record for annular disposal volumes Last Update Will All wells highlighed In blue are within a quater mile 1320 estedt.&''dj:losae of "Hera-ProdlleL" ti:eaxt uA fluids frm'the' . T'N' ancY ShAttntiAr Yau.hapd rcgu iris as aed11 as the clean u8 fluids, r6sultint! ;cutins, ' mxin5 ofmud and.cement•at Alp„ ling oil base iu$, from claaninA out the kankarat•the.mu$ giant in preparation for 12 cliza The eoPxOvad dis$oain4'of the "new product" clean uP �t;�igAioti hil$ previvusS,X' C1t�ids $1d d1ass 2 disposal.ogtions via annular dispb'sal pit CD 'i p2t�• C1aa8 1 Duc: tc the geolo5ical'sOttino. at Aipine. e�ltrahiiatied chis 1. isii:tatiatt of Liinitstt,� Philli8e Pz ccs rove$ as s CoYntt1H31An's. sariefefction at'a.annulai.disli'sal'vis agg optibas.t' . tiza ranmental alternative. approved prtand envl iri'thee, thee, Yadue9L'e the waste fluids are no d1"�tecent Chan previously d elolimrit activities at Alpine- of and au. this ttlessa4a•- BY COPY . a;a t%e teqult,• of hie.Ani3th0r. • ed . The t`6slmtieeiorisrs: •have'autl�arl.3ad me co send Y email. Phillips is authorised to dispose of'clsan up EluidA-as described in your X61_ Pieties c411 with any qusst:a.ons- . 'em Mauh&xf PL' • .�.r. Pekz'leuta Engi11e8r , AOGCC . ALP'isnV coord Y7relt"" > DeaXt Mr. maunder, r - ested a aa' noted its thA +aCCaChed otua3,1, 'Com Manson nraviouslyratt quna via dnmplar . > attaixox3,zation to-dieipose• of new -Product clean ug €"raids such as cemaut > riasate,• and muu. anft; 7ir5.ny Pit ririsFs4 sin 1.. �D2iD ill 5il:s. Ayadton ow, the > iii�ection in Perinitts¢. vigi.i.� at the. nkP a 1�C+CC a�jtirdtied. such disPcsal at tlsa� CDl EacilitXL�dnthe9on-bite dYi11ing a integral- reiationsilip of the mud mixing > opexation- - fLcant. Sian. > ursuins this tenu9et•xeSi�''ion,£ox tlie- o-.Philiips.wcssld like .ko aoatinuing P in months. > out of tAnks at tlie:matd mixisiy €afl G�Yx hlPineuin le-com B > t ptr •X use of, oil basad mud for tank. rinse fluids and Of annui.ax disposal'ae-an option routine > The trrailabiiitY fao�litasa thin ProaessConcernrahlout tb4 > similax re b figiallyereupp. hlrrrevor, there Lw Q a A ;ale City di' €luid that -coup? bs generhteil during this 1 Yg > ri.nsee are > potential ci7a7? , > clean up priicass.l vad > ,mud mixing facility MW UOntaln either near andbusidnj dtod in . > 'ranks e;. rfnass in contact with used products »Y. 'duces would > products. Though CCililllr rinses ..'£ new pr > the pg=uu.tted class- Sl:C is oea3 'se'lz (d619'sal' well. IOD -102i , wl>mr'e ther9 is pbteftrt -0uY bt rout d. onteht. 'The itl&eii I Well is a c1gn tor ? p,'d,{£firuley mah6ging ridlida c romise to this > lifelici@ f6# fatality, ixlf#a'fttru'ceuX$r being t-:) --ah5� comprOP,an for: s > dottiest;' effluaxlt:,, and it is a 8xiority to PT' o ef¢rred' waste management >'disposak facility• Annular disposai 9ressnts a PY > Alternative in this case. Note to File CRU CD5-18 (PTD 216-111) January 26, 2018 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-18 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well C135-18. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-3/4" surface casing shoe is set in this well at -2,117' true vertical depth subsea', near the base of a 450 to 480 -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 108' from the wellbore. 8. If injected wastes reach 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 CD5-18 and twenty-two 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 Sections 17-18, TI IN, 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 to 480 -foot thick interval that is dominated by claystone and ' 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. ' CRU C135-01, CD5-02, CD5-03, C135-04, C135-05, CD5-06, CO -07, CD5-08, C135-09, C135-1 0, CD5-11, C135-1 2, CD5-17, CD5-19, C135-20, CD5-21, C135-22, CD5-99, CD5-313, CD5-314X, Cd5-315, and C135-316. CD5-18 Annular Disposal Note to File January 26, 2018 Page 2 of 7 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 2, below). The annulus open to the disposal interval extends downward from the surface casing shoe at -2,117' to the top of cement for the 7-5/8" casing string, which is estimated to be -3,724'. The portion of the open annulus that will most likely accept the injected waste is a 138 -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 -2,240' and -2,378'. The aggregate thickness of these thin, potential receptor beds is about 36'. 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. 41/1 a. ITOM1 r�.` �1 �`���� a e 1 3' 1',1' i` 1 1 1 00 111 111 �• �iil 4111 11 111 111 111 Quarter mile radius circle,y ,.. 00 111 •�_�� Q•+ 111 •. ;1110,v i 1 !'!'! ` X111 111 111 �-50111 11 0 0.5 mile Figure 1. CD5-18 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 2.) The index map above displays trajectories for all wells drilled from and near the Colville River Unit CD5 Drill Site. Short tick -marks have been placed along each well trajectory at intervals of 500' measured depth below sea level, and they are labeled every 1,000'. The locations of the surface casing shoes for all well bores are illustrated using green -colored triangles. The calculated locations of the tops of cement for production casing strings are indicated by orange -colored triangles. The portions of each well bore that lie CD5-18 Annular Disposal Note to File January 26, 2018 Page 3 of 7 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. The V4 -mile radius area of review surrounding the proposed disposal interval in CD5-18 is highlighted on Figure 1 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. In CD5-18, the open annulus lies between -2,117' and -3,724', with the most likely waste -disposal interval between -2,240' and -2,378' (see Figures 1 and 2). Twenty-two wells are currently open to these same strata within the'/ -mile radius area of review. Figure 2, below, presents a west to southeast trending structural cross-section view of CD5-18 and nearby wells CD5-21 and CD5-313. CD5-313 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 1,040' above the top of the proposed disposal interval. CD5-18 Annular Disposal Note to File January 26, 2018 Page 4 of 7 Figure 2. CD5-18 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level) 2180310 W 501032073800 2181110 501032075000 2150840 501032071400 SE 4 60fl 100 ft 1,► CONOCOPHILLIPS CONOCOPHILLIPS CONOCOPHILLIPS CRU CDS-21 CRU CD&18 CRU C05.313 408 FNL 2823 FEL 391' FNL 2788' FEL 382 FNL 2870 FEL TWP 11 N - Range: 4 E - Sec. 18 TWP: 11 N - Range: 4 E - Sec. 18 TWP: 11 N - Range:4 E - Sec. 18 MIS101101 MA t __ iSOON_ ANNE ;. _ 1 'fid5e Of _ Perrnafl Os[ Surface { Upper / Casing _ Confining T Shoes _ 3 Interval Most Likely ower - Disposal _ nfining Interval _ ntervals _ Open .; Annulus - - ' TD 12,493' MD TD 27,089' MD TD 20 835' MD Figure 2. CD5-18 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level) CD5-18 Annular Disposal Note to File January 26, 2018 Page 5 of 7 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. 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. For CD5-18, top of cement is 5,650' MD (-3,724' TVDss) in the intermediate casing which covers the uppermost hydrocarbon bearing zone, Qannik. No oil bearing zones have been identified above this depth. 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. 200 180 180 140 120 100 80 80 40 20 Injected Fluid vs Affected Area Surrounding CD5-18 Wellbore (Assumptions: 30% porosity, 50% native fluid displacement, aggregate cylinder 38' high) i \/moi II i 1 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. CD5-18 Area Likely Affected by Annular Injection (Assuming piston -like, radial displacement of 50% of native formation fluids) The gamma ray curve recorded in CD5-18 indicates that about 36' 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 CD5-18 Annular Disposal Note to File January 26, 2018 Page 6 of 7 radius of about 108' from the wellbore, assuming uniform, radial, piston -like displacement of the native formation fluid occurs (Figure 3). 500 550 0 500 m � 450 E 400 a £ 350 a e J 305 M 250 a 200 E 155 N 100 3 u 50 e u Injected Fluid vs Affected Area Surrounding CD5-18 Wellbore (Assumptions: 30% porosity, 50% native fluid displacement, elliptical aggregate cylinder W high) 5,000 10,000 15.000 20,000 Amount of aMected Fluid (barrels) 25,000 30.000 35,000 Figure 4. Length of Semi -Major Axis (b) of Elliptical Cylinder Affected by CD5-18 Injection (Assuming piston -like, displacement of 50% of native formation fluids within in an elliptical cylinder having semi -minor axis length (a) of 341) The chart presented in Figure 4 provides an alternative estimate of the volume around CD5-18 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 36' 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 34' on either side of the CD5-18 wellbore, the semi -major axis of the affected elliptical cylinder may reach up to about 340' in length. The nearest surface casing shoe occurs in well CD5-315, which is located about 261' east of the surface casing shoe in CD5-18. So, with a strong west—trending directional influence on horizontal permeability, fluids injected into the CD5-18 annulus may reach the open annulus beneath surface casing in CD5-315. However, the operator's surface casing cementing records for CD5-315 reports good cement returns to the surface.' ' ConocoPhillips Alaska, Inc., Cement Detail Report for CRU CD5-315, dated September 8, 2015. CD5-18 Annular Disposal Note to File Summary January 26, 2018 Page 7 of 7 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. I recommend approving this proposed annular disposal within CRU CD5-18 to the limit of 35,000 barrels. Patricia Bettis Senior Petroleum Geologist Note to File C105-18 (PTD 216111, Sundry 318-022) 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 (CD5-18). 10 3/4" Surface casing was cemented to surface successfully. No problems were reported. Approximately 183 bbls of good cement was circulated to surface. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 12/5/2016, the pressure slope rises smoothly with test stopping at 1.3 bbl pumped and 960 psi to yield a 18.0 EMW. The pressure declined slightly from 960 psi to 895 psi (17.4 EMW) during the 10 minute shut in period. The initial FIT indicates that the surface casing shoe is well cemented. -- The 7.625" casing was run and successfully cemented with a 2 stage job with stage collar at 6350 ft MD and shoe of 15251 ft. Cement is estimated at TOC 5650 ft to the stage collar of 6350 ft and the shoe cement from TOC estimated at 12796 ft to TD. Cement job with full returns throughout. Annular disposal zone estimated from cemented 10.75" shoe at 2188 ft TVD to 2nd stage TOC estimated at 3795 ft TVD. A post cement 10.75 x 7.625" annulus injectivity test LOT was performed 12/17/2016 with a calculated depth of the casing shoe of 2391 ft MD, 2188 ft TVD and an open hole to est. TOC 5683 ft (3292 ft MD open) yielding a 16.2 ppg EMW. The test showed pressure rising steadily with a slight gradient change at the 14.5 ppg and the sharp break over point at the 16.2 ppg EMW. --There are multiple wells currently drilled or planned to be drilled within '/< mile radius of CD5- 18 and the CPAI application contains supporting cementing and LOT well information and mentions that well and cementing information is already on file with AOGCC. The surface shoe of CD5-314PB is closest, about 154' distant. CD5-315 at 261 ft, and CD5-313 is 268 ft distant. AD is already prolific on CD5 and it is expected to continue with additional CD5 wells. 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 January 23, 2018 G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\180123_CD5-18 note to file.doc • • Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent Tuesday, February 13, 2018 8:40 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject CRU CD5-18 (PTD 216-111) Report of Conductor Water Flow Follow Up Flag: Follow up Flag Status: Flagged Victoria, CRU producer D5-18(PTD 216-111) as recently been noted by operations to have water flowing to surface through the surface casing by conductor annulus. CPAI suspects this water to be from the same shallow source water that was encountered on CD5-313 (PTD 215-084),as well as other CD5 wells. At present the water flow rate is"4-5 gallons per day. We've taken initial samples for analysis and are collecting water at the wellhead to monitor the flow volume. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNEV k t: r 0 o . 9 o NN • I I rI . '_ N O i Z Z Z m as cu N E N _ E E •o = aO ¢ ¢ ¢ p cow m c n o n nM mmN NN I\ .- I V O OOZ J ❑❑ ❑O ❑O CI °❑ VVUV �I 0 ❑M Ua2 Lu w w I- I❑ I❑ I 0 v O i ZZ D › CO int 2 10 I 3> _� aa 6 O fc) 1 0 o = ❑ cO )= = F. 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O Q o a Z 0 D £ U Z d III 0 0 1 ✓ H a `° 3 N d N — a' D• opo w N. N C U .Q C7 E 0 O • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2--- tO(') 1.Operations Abandon r Plug Perforations r Fracture Stimulate P.' Tubing E Operations Shutdown E Performed: Suspend r Perforate E Other Stimulate r Alter Casing r Change Approved Program E Plug for Redrill E Perforate New Pool r Repair Well r Re-enter Susp Well E r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development P Explorator r 216-111 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20750-00 7.Property Designation(Lease Number): 8.Well Name and Number: ASRC NPR4,ASRC NPR2,ASRC-AA092344 CRU CD5-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 27089 feet Plugs(measured) None true vertical 7809 feet Junk(measured) None Effective Depth measured 26983 feet Packer(measured) 13517, 14062 true vertical 7805 feet (true vertical) 7393,7521 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 115 115 SURFACE 2354 15.27 2391 2187 INTERMEDIATE 15217 8.5 15251 7633 A SAND LINER 12866 5.5 26984 7805 RECEIVED Perforation depth: Measured depth: 21590-15623AP q it n Q 2017 True Vertical Depth: 7717-7639 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 14125 MD,7529 TVD Packers&SSSV(type,MD,and TVD) PACKER-HALIBURTON TNT PACKER, HYD563' ASSY#1 @ 13517 MD and 7393 TVD PACKER-HALIBURTON TNT PACKER, HYD563' ASSY#1 @ 14062 MD and 7521 ND PACKER-HRDE ZXP LINER TOP PACKER @ 14118 MD AND 7528 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 21590-15623 Treatment descriptions including volumes used and final pressure: Total Well-8 stages 656,000 lbs 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 N/A N/A N/A 0 0 Subsequent to operation 3439 1902 51 1456 224 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F 'y1'11 Exploratory E Development F Service r Stratigraphic r Copies of Logs and Surveys Run r (� 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation Data F GSTOR rWINJ r WAG r GINJ r SUSP r SPLUG r- 17. 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: 317-025 Contact Hanna Sylte, 907-265-6342 Email Hanna.SylteaConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer Signature AI Phone:265-6342 Date I % 12C U9- I .5 v Form 10-404 Revised 5/2015 RBD `) Submit Original Only Cji,.J 3/4i/2)i7 2' ��Ll' 1 a,;.�, - 8 G ,; • • CD5- 18 DTTMSTi JOBTYP SUMMARYOPS 2/2/17 TEMPORARY PULLED KEYLESS XN PLUG @ 14087' RKB. BRUSH AND FLUSHED TBG DWN NETWORK TO XN NIP @ 14087' RKB w/ FULL BORE BUSH, 2.79" G-RING. CHANGE OUT TO ONLY DAY CREW. IN PROGRESS 2/3/17 TEMPORARY ENGAGE SLDG SLEEVE @ 13548'RKB. PASS THROUGH. SET KEYLESS 2.81" NETWORK XN PLUG @ 14087'RKB. MIT TO 5000PSI. PASSED. CHANGE OUT w/ NIGHT ONLY CREW. IN PROGRESS... 2/3/17 TEMPORARY PULLED KEYLESS XN PLUG @ 14087' RKB. VERIFIED CMU @ 13548' RKB IS NETWORK FULLY CLOSED. DRIFT TBG TO 25' SLM w/3.895"G-RING. READY FOR FRAC. ONLY COMPLETE 2/8/17 FRACTURING Pumped stages 1-8, placing 656,000 lbs 20/40 Walnli proppant. -Stage 1: 67.7/71.9K lbs at 22 bpm -Stage 2: 84.7/83.1K lbs at 24 bpm -Stage 3: 90.7/90.1K lbs at 22 bpm -Stage 4: 90.3/90.1 K lbs at 24 bpm -Stage 5: 90.2/90.1K lbs at 23 bpm -Stage 6: 48/90.1K lbs at 23 bpm -Stage 7: 90.4/90.1K lbs at 23 bpm -Stage 8: 94/90.1K lbs at 24 bpm -Job Total: 656,000 lbs placed, 94% of design Hydraulic Fracturing Fluid Productipponent Information Disclosure • Fracture Date 2017-02-07 State: Alaska County: Harrison Bay API Number: 0510320750 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: CD5-18 Longitude:_ -150.22 Latitude: 70.31 Long/Lat Projection: Indian/Federal: none Production Type: True Vertical Depth(TVD): 0 Total Water Volume(gal)`: 412,563 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Number(CAS (%by mass)** HF Fluid(%by #) mass)** Sea Water Operator Base Fluid Water 7732-18-5 96.00% 79.86913% BE-6 Halliburton Biocide Listed Below Listed Below MICROBIOCIDE CL-22 UC Halliburton Crosslinker Listed Below Listed Below CL-31 Halliburton Crosslinker Listed Below Listed Below CROSSLINKER LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below MO-67 Halliburton pH Control Additive Listed Below Listed Below OPTIFLO-III DELAYED Halliburton Breaker Listed Below Listed Below RELEASE BREAKER SP BREAKER Halliburton Breaker Listed Below Listed Below WG-36 GELLING Halliburton Gelling Agent Listed Below Listed Below AGENT LVT-200 Penreco Additive Listed Below Listed Below Xinmi Wanli Wanli 20/40 Industry Proppant Listed Below Listed Below Developmen t Co.,Ltd MSDS and Non-MSDS Ingredients are listed below the green line Ingredients Listed Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00067% Above 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00184% Acrylate polymer Proprietary 1.00% 0.00115% Ammonium persulfate 7727-54-0 100.00% 0.01885% Corundum 1302-74-5 55.00% 8.99856% Crystalline silica,quartz 14808-60-7 30.00% 0.00577% Cured acrylic resin Proprietary 30.00% 0.00565% Ethanol 64-17-5 60.00% 0.04039% Guar gum 9000-30-0 100.00% 0.21940% Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02020% Hydrotreated Distillate,Light..C9-16 64742-47-8 100.00% 0.75208% Mullite 1302-93-8 95.00% 6.95337% Naphthalene 91-20-3 5.00% 0.00337% Oxylated phenolic resin Proprietary 30.00% 0.02693% Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00337% branched Potassium formate 590-29-4 60.00% 0.06893% Potassium hydroxide 1310-58-3 5.00% 0.00251% Potassium metaborate 13709-94-9 60.00% 0.03007% Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00115% Sodium chloride 7647-14-5 4.00% 3.33029% •Sodium glycollate 2836-32-0 1.00% 0.00115% Sodium hydroxide 1310-73-2 • 30.00% 0.03790% Sodium persulfate 7775-27-1 100.00% 0.00024% Sodium sulfate 7757-82-6 0.10% 0.00000% Ulexite,calcined 92908-33-3 60.00% 0.06893% Water 7732-18-5 100.00% 0.19088% *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 supplier who provided it. The Occupational Safety and Health Administration's(OSHA)regulations govern the criteria for the disclosure of this information. Plea criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.12000)and Appendix D. Ingredient Mass Comments Company First Name Last Name Email Phone lbs 3390267 Density=8.560 0 NA 0 NA O NA 0 NA O NA 0 NA O NA 0 NA 0 NA 0 NA 29 78 Denise Tuck, Halliburton,3000 N.Sam Houston Denise.Tuck 49 Pkwy E., Houston, Halliburton Denise Tuck @Halliburton.c 281-871-6226 TX 77032,281- om 871-6226 800 360746 245 Denise.Tuck 240 Halliburton Denise Tuck @Halliburton.c 281-871-6226 om 1715 9313 858 31925 295156 143 Denise.Tuck 1144 Halliburton Denise Tuck @Halliburton.c 281-871-6226 om 143 2926 107 1277 49 141365 49 •1609 11 1 2926 8104 v3 3 and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the ise note that Federal Law protects"proprietary","trade secret",and"confidential business information"and the WNSD 411 CD5-18 ConocoPll 11ps Well Attributes Max Angle&MD TD Alaska.Ir11,,, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CarpcoDhinips 501032075000 ALPINE PROD 27,089.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD5-18,318/2017.8:02:48 AM SSSV:NIPPLE LAST WO: 36.90 1/21/2017 Versoal eohema9c.:(actuate Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;201 a_:-,-,■ LAST Tag: Rev Reason:NEW WELL 8 FRAC pproven 3/7/2017 Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread � �� �I CONDUCTOR 20 19.124 36.6 115.0B) 115.0 78.60 B Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 60 Grade Top Thread f SURFACE 103/4 9.950 36.5 2,390.9 2,187.7 45.50 L-80 Hyd 563 Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;36.6-115.0 a. INTERMEDIATE 75/8 6.875 34.1 15,251.0 7,633.3 29.70 L80 BTCM NIPPLE;2,135.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread A SAND LINER 4 1/2 3.958 14,118.0 26,983.5 7,804.9 12.60 L-80 TXP I Liner Details Nominal ID SURFACE;36.52,390.9 Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (In) 14,118.0 7,527.8 83.38 PACKER Liner Top Packer,HRDE ZXP,w/11.18'SBE 4.820 ME GAS LIFT;4,956.9 tar 14,137.9 7,530.0 83.64 NIPPLE RS Nipple,5-1/2",Hyd563 4.250 ans 14,140.2 7,530.3 83.67 HANGER Liner Hanger,DG FL pinned 2500 psi 4.810 1 I 14,149.8 7,531.3 83.79 XO Reducing XO,L-80,5 1/2"Hyd563 Box X 4 1/2"TXP Pin 3.920 GAS LIFT;9,515.0 15,627.4 7,639.5 89.48 FRAC PORT Baker Express Frac Sleeve#8(2.125 ball,2.063" 2.063 seat) 16,536.1 7,646.9 90.11 FRAC PORT Baker Express Frac Sleeve#7(2.063"ball,2.0"seat) 2.000 GAS LIFT;13,303.2 • 17,524.1 7,673.3 86.49 FRAC PORT Baker Express Frac Sleeve#6(2"ball,1.96"seat) 1.960 IIIN GAUGE;13,456.4 18,356.3 7,689.3 88.60 FRAC PORT Baker Express Frac Sleeve#5(1.938"ball,1.90" 1.900 11 seat) liEll 19,145.3 7,692.6 89.96 FRAC PORT Baker Express Frac Sleeve#4(1.875"ball,1.813" 1.813 PACKER;13,518.5 '- seat) SLIDING SW;13,541.7 •-I 19,973.7 7,697.9 89.12 FRAC PORT Baker Express Frac Sleeve#3(1.813"ball,1.78" 1.780 NIPPLE;13,557.5 ' seat) 111 20,798.1 7,710.5 89.20 FRAC PORT Baker Express Frac Sleeve#2(1.750"ball,1.71" 1.700 seat) PACKER;14,061,7 21,593.8 7,717.2 89.05 FRAC PORT Baker Express Frac Sleeve#1(1.688"ball,1.65" 1.650 Seat) NIPPLE;14,080.9 PLUG;14,092.7 F Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection LOCATOR;14,109.3 _ TUBING 1 31/21 2.9921 25.11 14,125.91 7,528.71 9.301 L-80 I EUE8rdM LOCATOR;14,110.4 •fit♦ .11 Completion Details MULE SHOE;14,124.9 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.1 25.1 0.00 HANGER FMC 4-1/2"Tubing Hanger TXP 3.958 1' I 67.9 67.9 0.22 XO Reducing CROSSOVER,41/2"TXP X 3 1/2"EUE,BP 2.992 I 2,135.5 1,997.9 40.10 NIPPLE Landing Nipple,3-1/2",X,2.813",EUE-8rd-2,000'tvd 2.813 13,456.4 7,373.5 70.15 GAUGE SLB Gauge Carrier,9.3#L-80 EUE-8rd PinxPin w/top 2.913 INTERMEDIATE;34.1-15,251.0 coupling Hydraulic Fracture;15,823,0 I I 13,516.5 7,393.3 71.37 PACKER Haliburton TNT Packer,HYD563'Assy#1 2.992 I 13,541.7 7,401.2 71.88 SLIDING SLV 3.5"SLEEVE,SLIDING,31/2",APCV-11,2.813" 2.813 13,557.5 7,406.1 72.15 NIPPLE NIPPLE,LANDING,3 1/2",X,2.813",EUE8RDM,High Burst 2.813 Hydraulic Fracture;16,532.0 I I 1 14,061.7 7,520.8 82.43 PACKER Haliburton TNT Packer,HYD563'Assy#1 2.900 14,080.9 7,523.3 82.76 NIPPLE NIPPLE,LANDING,3 1/2",XN,2.813",EUE8RDM,2.75 no- 2.750 go Hydraulic Fracture;17,520.0 I I 14,092.7 7,524.8 82.96 PLUG Haliburton Mirage Plug,VAMTOP 2.880 I 14,109.4 7,526.8 83.25 LOCATOR Mechanical locator,EUE("OD locator) 3.000 Hydraulic Fracture;15,352.0 I I 14,110.4 7,526.9 8327 LOCATOR Mechanical locator shear sub(.5'to shear screws) 3.000 I I 14,124.9 7,528.6 83.47 MULE SHOE Baker WLEG 2.990 Stimulations&Treatments Hydraulic Fracture;19,141.0 I I Proppant Designed(Ib) Proppant In Formation(Ib) Date 4 696,300.0 655,900.0 2/8/2017 Stimulations&Treatments Vol Clean Pump Hydrauoc Fracture;19,970.0 I I Stg# Top(ftKB) Stet(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) I 1 1 21,590.0 21,591.0 2/8/2017 Hybor G,Gelled Salt Water 2532.00 2602.00 2 20,794.0 20,795.0 2/8/2017 Hybor G,Gelled Salt Water 1136.00 1223.00 Hydraulic Fracture:20784.0 I I 3 19,970.0 19,971.0 2/8/2017 Hybor G,Gelled Salt Water 893.00 986.00 1 4 15,623.0 15,624.0 2/8/2017 Hybor G,Gelled Salt Water 1044.00 1140.00 5 18,352.0 18,353.0 2/8/2017 Hybor G,Gelled Salt Water 898.00 991.00 Hydraulic Fracture;21,590.0 I I 6 17,520.0 17,521.0 2/8/2017 Hybor G,Gelled Salt Water 798.00 847.00 7 16,532.0 16,533.0 2/8/2017 Hybor G,Gelled Salt Water 930.00 1023.00 i 8 19,141.0 19,142.0 2/8/2017 Hybor G,Gelled Salt Water 1652.00 1745.00 Mandrel Inserts m St IMII an on Top)1VD) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com gift 1 4,956.9 3,474.4 Camco KBMG 1 GAS LIFT DMY BEK-5 0.000 0.0 1/18/2017 2 9,515.0 5,577.3 Camco KBMG ' 1 GAS LIFT DMY BEK-5 0.000 0.0 1/18/2017 NM 3 13,303.2 7,316.9 Camco KBMG ' 1 GAS LIFT SOV BEK-5 0.000 0.0'1/18/2017 2500 NM , psi I` Notes:General&Safety End Date 1 Annotation Mali NOTE: Il.. Gni EEO MEI A SAND LINER;14,116.0- 26,98351 1 l RECEIVED • STATE OF ALASKA 4110FEB 1 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANMD la.Well Status: Oil 2 6 Gasp SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 . Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or IlIct+ti- 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 44291z''9fiff i,, 216-111 / ` 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 12/1/2016 50-103-20750-00-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 391'FNL,2766'FEL,Sec 18,T11N, R4E, UM 12/24/2016 CRU CD5-18 1 Top of Productive Interval: 9.Ref Elevations: KB:70.8 17.Field/Pool(s): 3162'FNL,4312'FEL,Sec 21,T11N,R4E, UM GL:33.9 BF: Colville River Unit/Alpine Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3041'FNL,3991'FEL,Sec 34,T11N,R4E, UM 26,983/7805 • ASRC-NPR2,NPR4,ASRC-AA092344 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 349912 y- 5965824 Zone- 4 27089/7809 . 932128,932669,340757 TPI: x- 358093 y- 5957599 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 363523 y- 5947058 Zone- 4 N/A 1345/1321 5. Directional or Inclination Survey: Yes (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) I 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 I V all SCWT 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 B 37 115 37 115 42 10 yds 10 3/4 45.5 L-80 36 2391 36 2188 13 1/2 934 sx 11.0 ppg LiteCrete, 240 sx 15.8 ooa Class G 7 5/8 29.7 L-80 34 15251 34 7633 9 7/8 x 11 Stage 1:1036 sx 15.8 ppg Class G Stage 2:276 sx 15.8 non Class G 4 1/2 12.6 L-80 14118 26983 7528 7805 6 3/4 Uncemented liner w/frac ports 24.Open to production or injection? Yes D 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 1/2 14126 13516/7393 LINER w/FRAC PORTS @ 14118/7528 15627 MD and 7639 TVD, 16536 MD and 7647 TVD .;OMP`E;Oki 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 17524 MD and 7673 TVD, 18356 MD and 7689 ND "/AV, Was hydraulic fracturing used during completion? Yes❑ No ❑ 19145 MD and 7693 ND, 19974 MD and 7698 ND ///q l 20798 MD and 7710 TVD,21594 MD and 7717 TVD r Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cc 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): LL 1/ZQj ill- WAITING FOR FLOW BACK (I i S L Ilr'f- Date ofTest: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: kh.bif t/ �."�S Test Period q(p'Z 02 ��� L .Z�Loc..; (01Z1 Flow Tubing Casing Press: Calculated Oil-BlI3 Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 911 1(o L-(v 24-Hour Rate -3 SPS 1�2(P 1�, �l� frm 1 407 vised 11/201J5/ ��L g�2ii`1 CONTINUED ON PAGE 2 RBDMS VU FEB 1 4 2017 Submit ORIGINIAL onl Il 1/0111 �/��7 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No E 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 ND Well tested? Yes ❑ No ❑ 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 15218 7631 information, including reports,per 20 AAC 25.071. C30 22571 2313 K3 5650 3790 K2 6183 4037 Albian 97 7714 4743 Albian 96 10117 5852 HRZ 12728 7060 Kalubik 13034 7201 Kuparuk C 13297 7314 LCU/Miluveach 13308 7319 Alpine 13925 7499 Alpine C 13982 7509 UJU 14044 7518 Alpine A 15218 7631 Formation at total depth: Alpine A Sand I 31. List of Attachments: Daily Operations Summary,Cement Report, Definitive Survey,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.Production or well test results.Per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: William Earhart @ 265-1077 Email: William.C.EarhartOcop.com kJ LV Printed Name: G. L.Alvord Title: Alaska Drilling Manager Signature: - - Qt_ Phone: 265-6120 Date: Zi 13 11017 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 ND 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 • 0 . CD5 - 18 Alpine A/C Dual Lateral Producer 20"94#H-40 Welded Upper Completion: 4 k Conductor to 115' MD 1)3-Y2"9.3#/ft eue8rd 2)Shallow X nipple profile 2.813" ID 3)3-'h"x 1" Camco KBMG GLM(xx°)w/DCK2 pinned for 2500 psi casing to tbg shear iii 4)HES TNT Packer 2.813"X Nipple 5)CMU sliding sleeve 2,014' MD 6)X Nipple 2.813"ID • 7)HES TNT Packer 1 1 8)XN Nipple 2.813" ID 10-3/4" 60#L-80 BTC 9)Mirage Plug A , Surface Casing at 2,390' MD Lower Completion: 7)Plop and drop liner in C sand -no junction -4.5"12.6#L-80 w/perf pups ® 8)ZXP liner top packer&Flexlock Liner Hanger XO 5" Hydril 521 Box X 4-%"IBTM pin -4.5" 12 6#L-80 w/ Frac Ports and Perf Pups 3 112" 9.3#L 80 eue8rd&9.3# Stage MD Baffle ID Ball Size TN110 H563 DHG 13,462 14 ?25 8 15,623 2.073" 2.125" 7 16,532 2.035" 2.063" 6 17,520 1.948" 2" ® 5 18,352 1.883" 1.938" 4 19,141 1.823" 1.875" 3 19,970 1.780" 1.813" 2 20,794 1.705" 1.75". 1 21,590 1.636" 1.688" 7 5/8"29#L-80 Hyd 563 Intermediate Casing at 15,251'MD C sand Lateral 6 3/4"Hole TD 3-1/2" 9.3#TN110SS 14,012'-27,000'MD N �I 4'/2"12.6#L-80 Liner w/perf pups / 0 0 0 0 ,) TNT Production / .::::,... „ Packer at 13,532'MD.::, — CMU Sliding Sleeve';:;;, /��� 4'/z"12.6#L-80 Liner w/frac ports and perf pups 13 548' l''-..,,,i,..%.. 0 0 ou off 0 0 O o 0 0 0 00 2.813"X Nipple 13,568 MD ''- I — TNT Production Packer 14,048'MD � _____ ____! A sand Lateral 6 3/4"Hole TD Mirage Plug 14,083'MD ZXP liner top packer(whipstock 15,067'—26,981'MD base)at 14,114'MD 2.813"XN Nipple 14,068'MD 'orations Summary (with Timelog Crepths) CD5-18 • k C Phltlips "p. 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) 11/30/2016 11/30/2016 1.00 MIRU MOVE RURD P B/D steam lines and disconnect 0.0 0.0 20:00 21:00 cables. 11/30/2016 12/1/2016 3.00 MIRU MOVE MOB P Spot Ball mill,move pipe shed from 0.0 0.0 21:00 00:00 sub,skid rig floor and jack up sub. 12/1/2016 12/1/2016 4.00 MIRU MOVE MOB P Move pits,ball mill,and sub over to 0.0 0.0 00:00 04:00 CD5-18 12/1/2016 12/1/2016 1.00 MIRU MOVE MOB P Lower stompers and skid rig floor in to 0.0 0.0 04:00 05:00 position. 12/1/2016 12/1/2016 1.00 MIRU MOVE MOB P Moved and spotted pits to the Sub. 0.0 0.0 05:00 06:00 12/1/2016 12/1/2016 1.00 MIRU MOVE RURD P Connect steam lines,air,water, 0.0 0.0 06:00 07:00 electrical and fuel lines. 12/1/2016 12/1/2016 1.00 MIRU MOVE RURD P Connect mud lines,bleeders,cement 0.0 0.0 07:00 08:00 lines and spot ball mill. 12/1/2016 12/1/2016 1.00 MIRU MOVE RURD P M/U valves on conductor and hook up 0.0 0.0 08:00 09:00 koomy unit. Sim-Ops,Gyro took surveys on rig floor referencing north. 12/1/2016 12/1/2016 2.00 MIRU MOVE RURD P Install surface riser,hook up flow 0.0 0.0 09:00 11:00 lines,and mud bucket line. Rig on hi-line at 10:50 hrs. 12/1/2016 12/1/2016 1.75 MIRU MOVE RURD P Work on rig acceptance checklist. 0.0 0.0 11:00 12:45 NOV working on shakers,welding. (Accept rig @ 12:45) 12/1/2016 12/1/2016 1.50 MIRU MOVE RURD P Work on pre-spud check list. Clean 0.0 0.0 12:45 14:15 and clear rig floor. take on mud to the pits and clear cellar area of CD5-99. 12/1/2016 12/1/2016 2.25 MIRU MOVE BHAH P M/U 13 1/2"surface BHA as per SLB. 0.0 115.0 14:15 16:30 12/1/2016 12/1/2016 3.00 MIRU MOVE RURD P R/U gyro and e-line,function annular 115.0 115.0 16:30 19:30 and pressure test mud lines. 12/1/2016 12/1/2016 0.50 MIRU MOVE SFTY P Pre-Spud meeting. Discussed well 115.0 115.0 19:30 20:00 hazards and response plans as well as lifting and dropped objects risk with e-line. 12/1/2016 12/1/2016 1.00 MIRU MOVE CIRC P Attempted to pump at 450 gpm with 115.0 115.0 20:00 21:00 mud climbing the riser due to being cold/thick(44 deg). Reduced to 350 gpm,450 psi and gradually build rate up to 400 gpm,580 psi as riser level allowed. 12/1/2016 12/1/2016 1.00 SURFAC DRILL DDRL P Tag bottom and drill f/115'to 186'MD 115.0 186.0 21:00 22:00 40 rpm,5/10k WOB,400 gpm,580 psi 12/1/2016 12/1/2016 1.00 SURFAC DRILL RGRP T 2 bolts on the bell guide sheared while 186.0 115.0 22:00 23:00 breaking out of TD. B/D TD,racked back a stand,placing bit in the conductor,and repaired sheared bolts. 12/1/2016 12/1/2016 0.50 SURFAC DRILL SVRG P Serviced TD and drawworks. 115.0 115.0 23:00 23:30 12/1/2016 12/2/2016 0.50 SURFAC DRILL SRVY P RIH to 186'MD and started taking 115.0 186.0 23:30 00:00 surveys to run gyro log. 12/2/2016 12/2/2016 0.50 SURFAC DRILL SRVY P Change out Gyro tool and take initial 186.0 186.0 00:00 00:30 survey at base of conductor. Page 1/38 Report Printed: 1/24/2017 1 Operations Summary (with Timelog Depths) C D5-18 a Conoc.oPhillips 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) 12/2/2016 12/2/2016 11.50 SURFAC DRILL DDRL P Directional drill from 186'MD to 1,109' 186.0 1,109.0 00:30 12:00 MD, 1,096'TVD.ADT=9.6,AST=3.02, ART=6.58.P/U=112k,S/O=95k, ROT=102k,TQ on/off=4.5/3.5k.490 gpm, 1250 psi,60 rpm. 12/2/2016 12/3/2016 12.00 SURFAC DRILL DDRL P Directional drill to TD from 1,109'MD 1,109.0 2,400.0 12:00 00:00 to 2,400'MD,2,195'TVD.ADT=7.3, AST=3.2,ART=4.1.P/U=130k, S/0=110k,ROT=120k,TQ on/off=6.5/4k.650 gpm, 1890 psi,60 rpm. 12/3/2016 12/3/2016 4.25 SURFAC CASING BKRM P Pumped 34 bbl NP sweep and 2,400.0 1,675.0 00:00 04:15 BROOH f/2,400'to 1,675'MD with 600-700 gpm,2540-2040 psi,60 rpm, and 3k TQ. Saw consistent hole unloading and had to reduce rate to reduce losses over the shakers. B/D TD and took P/U= 130k,S/0=115k. 12/3/2016 12/3/2016 0.25 SURFAC CASING OWFF P OWFF,Well static. 1,675.0 1,675.0 04:15 04:30 12/3/2016 12/3/2016 1.25 SURFAC CASING TRIP P POOH f/1,675'to 831'MD.Observed 1,675.0 831.0 04:30 05:45 tight spots at 1,500', 1,225',and 550' MD with—35k overpull. 12/3/2016 12/3/2016 0.25 SURFAC CASING OWFF P OWFF,Well Static. 831.0 831.0 05:45 06:00 12/3/2016 12/3/2016 2.25 SURFAC CASING BHAH P L/D 13 1/2"BHA as per SLB. R/B 5 831.0 0.0 06:00 08:15 stands HWDP,jars,and NMDC. Total trip calculated fill=21.4 bbl, actual=31 bbl 12/3/2016 12/3/2016 1.75 SURFAC CASING RURD P R/U Volant and 10 3/4"casing running 0.0 0.0 08:15 10:00 tools. Clear BHA handling tools from floor and L/D. Monitored well on TT with 11.5 bbl losses in 3 hrs. 12/3/2016 12/3/2016 6.50 SURFAC CASING PUTB P M/U 10 3/4"L-80 Hydrl 563 shoe 0.0 1,461.0 10:00 16:30 track,check floats and RIH to 1,461' MD as per tally. Had to wash through tight spots at 850'and 1,380'MD with 3 bpm, 130/240 psi. . 12/3/2016 12/3/2016 0.75 SURFAC CASING CIRC P Circulated and conditioned mud. 1,461.0 1,461.0 16:30 17:15 staged pumps up to 6 bpm with 340 psi. P/U=140k,S/O=90. 12/3/2016 12/3/2016 2.00 SURFAC CASING PUTB P Continue RIH f/1,464'to 2,391'MD 1,461.0 2,352.0 17:15 19:15 with 10 3/4"casing. 12/3/2016 12/3/2016 0.75 SURFAC CASING HOSO P M/U hanger and landing joint and land 2,352.0 2,391.0 19:15 20:00 casing at 2391'MD. 12/3/2016 12/3/2016 3.00 SURFAC CEMENT CIRC P Circulate and condition mud for 2,391.0 2,391.0 20:00 23:00 cement job. staged pumps up to 8 bpm with 200 psi.Dropped YP in 10 ppg mud to 18 cp. 12/3/2016 12/3/2016 0.50 SURFAC CEMENT RURD P B/D TD and R/U cement hose to 2,391.0 2,391.0 23:00 23:30 swivel. Close IBOP and manual valves. 12/3/2016 12/4/2016 0.50 SURFAC CEMENT CIRC P Circulate and condition mud at 8 bpm, 2,391.0 2,391.0 23:30 00:00 480 gpm,P/U= 150k,S/O=125k.Sim- Ops, Held Cement Pre-Job with crew coming on tour. Page 2/38 Report Printed: 1/24/2017 !perations Summary (with Timelog epths) CD5-18 ConocoMfr 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) 12/4/2016 12/4/2016 0.25 SURFAC CEMENT CIRC P Circulate and condition mud at 8 bpm, 2,391.0 2,391.0 00:00 00:15 490 gpm, P/U=150k,S/O=125k. 12/4/2016 12/4/2016 3.50 SURFAC CEMENT CMNT P Dowell PT lines to2700 psi, Dowell 2,391.0 2,391.0 00:15 03:45 pump 75.2 bbls 10.5 ppg Mud Push II w/4.2 bpm @ 350 psi,Drop btm plug, Dowell pump 40.2 bbl of 11# scavenger cmt.Followed by 278.5 bbls 11.0 ppg(935 sks-1.91 yld LiteCrete total)lead cement w/5 bpm @ 350 psi,Dowell pump 57 bbls 15.8 ppg(240 sks-1.17 yld Class G) 15.8 ppg tail cement w/3.6 bpm @ 420 psi, Drop top plug,Dowell pump 20 bbls water,5 bpm,560 psi,Rig chase with 202 bbls 10.0 ppg DrilPlex mud w/8 bpm @ 790 psi,slow to 3 bpm @ 450 psi last 10 bbls,and bump on schedule with 2008 stks @ 95.8%eff. Pressure up to 1020 psi&hold for 5 min.Check floats(good)CIP @ 03:26 hrs.Reciprocate pipe w/full returns. 183 bbls good cement to surface. 12/4/2016 12/4/2016 0.25 SURFAC CEMENT CIRC P Flush riser and 20"annular w/black 2,391.0 2,391.0 03:45 04:00 water at 9.5 bpm,and 400 psi. Pumped a total of 70 bbl and functioned annular 3 times before shutting in on landing joint. 12/4/2016 12/4/2016 1.50 SURFAC CEMENT WWSP P R/D volont,casing running tools,and 2,391.0 0.0 04:00 05:30 cement lines. B/D TD,cement,and mud lines. UD 10'pup on landing joint while WOC. 12/4/2016 12/4/2016 3.00 SURFAC CEMENT WOC P Service TD and drawworks while 0.0 0.0 05:30 08:30 WOC. Changed out encoder on DW. 12/4/2016 12/4/2016 1.50 SURFAC CEMENT WOC P P/U and M/U 9 7/8"x 11"intermediate 0.0 0.0 08:30 10:00 drilling BHA and rack back while WOC. 12/4/2016 12/4/2016 1.25 SURFAC CEMENT WOC P Clean pits while WOC. performed 0.0 0.0 10:00 11:15 PM2 work on TD. 12/4/2016 12/4/2016 2.00 SURFAC CEMENT WOC P P/U and R/B 15 stands of 5"NC50 DP 0.0 0.0 11:15 13:15 12/4/2016 12/4/2016 1.25 SURFAC CEMENT WOC P Slip&cut 53'of drill line. 0.0 0.0 13:15 14:30 12/4/2016 12/4/2016 0.75 SURFAC CEMENT WOC P Rack pack 2 stands of DP,M/U 10' 0.0 0.0 14:30 15:15 pup to landing joint and clear floor. 12/4/2016 12/4/2016 1.25 SURFAC CEMENT OWFF P Check annular pressure(vacume)and 0.0 0.0 15:15 16:30 open. Drain stack,monitor well and rinse riser. Function annular(no cmt contamination). 12/4/2016 12/4/2016 0.75 SURFAC CEMENT RURD P L/D landing joint and mouse hole. B/D 0.0 0.0 16:30 17:15 hole fill lines. 12/4/2016 12/4/2016 1.25 SURFAC CEMENT NUND P N/D flow line,hole fill,Bleeders,and 0.0 0.0 17:15 18:30 UD surface riser. 12/4/2016 12/4/2016 2.50 SURFAC CEMENT NUND P N/D 20"surface annular and set on 0.0 0.0 18:30 21:00 skid. N/D starting flange. 12/4/2016 12/5/2016 3.00 SURFAC WHDBOP NUND P N/U wellhead and BOPE. Test casing 0.0 0.0 21:00 00:00 hanger to 1000 psi for 10 min. 12/5/2016 12/5/2016 0.50 SURFAC WHDBOP NUND P Finish N/U BOPE on well head. 0.0 0.0 00:00 00:30 Page 3/38 Report Printed: 1/24/2017 0-4 0 Operations Summary (with Timeloglitths) CD5-18 Cotmcot''hiHips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/5/2016 12/5/2016 2.00 SURFAC WHDBOP MPDA P Installed MPD clamp,orbit valve, 0.0 0.0 00:30 02:30 Ketch-Kan,and flow/drain lines. 12/5/2016 12/5/2016 1.75 SURFAC WHDBOP RURD P Install mouse hole and set lower test 0.0 0.0 02:30 04:15 plug and MPD test plug in clamps. Connect choke,kill and flair lines to stack and throughout the rig. 12/5/2016 12/5/2016 1.75 SURFAC WHDBOP MPDA P Fill stack with water and test MPD 0.0 0.0 04:15 06:00 equipment to 200/1200 psi for 5 min and chart. Pulled MPD test plug and B/D system. Installed trip nipple and set 5"test joint in place. Filled choke and kill lines with water. 12/5/2016 12/5/2016 4.00 SURFAC WHDBOP BOPE P Test BOPE w/5"test joint.Annular, 0.0 0.0 06:00 10:00 HCR choke/kill 250/2500 psi for 5 min. Upper 3 1/2"X 6"VBR's,choke valves 1,12,13,14,auto IBOP,4"Demco, choke valves 9,11,man IBOP,HCR kill,needle valve,dart valve&choke valves 5,8,10 to 250/3500 psi for 5 min.Test choke valves#2-7, HCR Choke and Kill,man choke/kill,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= 1,500 psi,200 psi recovery 28 sec,full recovery 144 sec,N2-4 bottle average=2000 psi.Tested gas alarms.Draw down on man&super choke to 1,100 psi.Flushed gas buster.Test witness waived by Brian Bixby of the AOGCC 12/5/2016 12/5/2016 1.25 SURFAC WHDBOP RURD P R/D test equipment.L/D 5"test joint, 0.0 0.0 10:00 11:15 pull test plug,and install 10"wear ring as per FMC. 12/5/2016 12/5/2016 0.75 SURFAC CEMENT BHAH P M/U 9 7/8"x 11"Int. BHA as per SLB. 0.0 181.0 11:15 12:00 12/5/2016 12/5/2016 1.25 SURFAC CEMENT TRIP P RIH f/181'to 2,140'MD with 5" 181.0 2,140.0 12:00 13:15 HWDP and 5"DP from derrick. 12/5/2016 12/5/2016 0.75 SURFAC CEMENT DHEQ P Fill pipe and shallow test MWD at 675 2,140.0 2,140.0 13:15 14:00 gpm,2130 psi. 12/5/2016 12/5/2016 1.50 SURFAC CEMENT PRTS P R/U and pressure test casing to 3500 2,140.0 2,140.0 14:00 15:30 psi for 30 min. Test Good. 12/5/2016 12/5/2016 0.50 SURFAC CEMENT REAM P Wash down f/2,140'to 2,220'MD w/ 2,140.0 2,307.0 15:30 16:00 450 gpm,990 psi,30 rpm,and 4k TQ. P/U= 127,S/O=110,ROT= 120. Started washing through cmt f/2,220' to 2,307'MD. 12/5/2016 12/5/2016 3.50 SURFAC CEMENT DRLG P Drill out shoe track and 10'rat hole f/ 2,307.0 2,400.0 16:00 19:30 2,307'to 2,400'MD 475 gpm, 1170 psi,30 rpm,4-7.5k TQ. 12/5/2016 12/5/2016 0.50 SURFAC CEMENT DDRL P Drill 20'of new hole f/2,400'to 2,420' 2,400.0 2,420.0 19:30 20:00 MD and began displacing to 9.6 ppg LSND on the fly. 12/5/2016 12/5/2016 0.25 SURFAC CEMENT DISP P Finish displacing to 9.6 ppg LSND and 2,420.0 2,420.0 20:00 20:15 circulate BU. 12/5/2016 12/5/2016 0.25 SURFAC CEMENT RURD P R/U for FIT and B/D lines. 2,420.0 2,420.0 20:15 20:30 Page 4/38 Report Printed: 1/24/2017 Aerations Summary (with Timelog Depths) CD5-18 Con ocoPhithps 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 (ftKD) End Depth(ftK6) 12/5/2016 12/5/2016 1.00 SURFAC CEMENT FIT P FIT to 18 ppg EMW at 2,391'MD/ 2,420.0 2,420.0 20:30 21:30 2,188'TVD with 9.6 ppg mud in the hole and 960 psi at surface. Sim-Ops flushed MPD manifold and tested off line. 12/5/2016 12/5/2016 1.25 INTRMI DRILL DDRL P Drill f/2,420'to 2,518'MD. 2,420.0 2,518.0 21:30 22:45 12/5/2016 12/5/2016 0.75 INTRM1 DRILL CIRC P Took initial parameters of 600 gpm, 2,518.0 2,518.0 22:45 23:30 1370 psi,50 rpm,3k TQ,and 2265 TRPM. Dropped 1.25"Under reamer activation ball and pumped down. No indication of the ball was seen. Resumed original parameters and took readings again of 1010 psi 1718 TRPM. Pull tested against 10 3/4" shoe and observed 10k Overpull. (Underreamer Confirmed Open) 12/5/2016 12/6/2016 0.50 INTRM1 DRILL DDRL P Resumed drilling f/2,518'to 2,589' 2,518.0 2,589.0 23:30 00:00 MD TVD=2,324' 12/6/2016 12/6/2016 12.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 2,589.0 4,177.0 00:00 12:00 Intermediate hole from 2,589'MD to 4,177'MD.ADT=8.36 hrs.P/U=143k, S/0=120k, ROT=130k.830 gpm,2400 psi, 11.1 ppg ECD,150 rpm,Tq on/off=8k/5.5k. 12/6/2016 12/7/2016 12.00 INTRMI DRILL DDRL P Directional drill 9-7/8"x 11" 4,177.0 5,865.0 12:00 00:00 Intermediate hole from 4,177'MD to 5,865'MD,3,889'TVD.ADT=8.67 hrs. P/U=156k,S/0=124k, ROT=140k.830 gpm,3000 psi, 11.35 ppg ECD, 150 rpm,Tq on/off=10.5k/5.5k. 12/7/2016 12/7/2016 5.75 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 5,865.0 6,775.0 00:00 05:45 Intermediate hole from 5,865'MD to 6,775'MD,4,310'TVD.ADT=4.49 hrs. P/U=172k,S/0=135k,ROT=150k.830 gpm,2800 psi, 11.2 ppg ECD, 150 rpm,Tq on/off= 13.5k/9.5k. 12/7/2016 12/7/2016 0.50 INTRM1 DRILL SVRG P Circulate @ 500 gpm, 1030 psi, 100 6,775.0 6,775.0 05:45 06:15 rpm,8k Tq.Service rig while repairing drag chain in pits. 12/7/2016 12/7/2016 5.75 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 6,775.0 7,702.0 06:15 12:00 Intermediate hole from 6,775'MD to 7,702'MD,4,733'TVD.ADT=4.55 hrs. P/U=182k,5/0=145k,ROT=160k.830 gpm,2855 psi, 11.28 ppg ECD, 150 rpm,Tq on/off=15k/10.5k. 12/7/2016 12/7/2016 6.50 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 7,702.0 8,673.0 12:00 18:30 Intermediate hole from 7,702'MD to 8,673'MD,5,186'TVD.ADT=4.79 hrs. P/U=187k,5/0=145k,ROT=165k.830 gpm,2900 psi, 11.2 ppg ECD, 150 rpm,Tq on/off= 18k/10.5k. 12/7/2016 12/7/2016 1.00 INTRM1 DRILL RGRP T Air boot failure on trip nipple,would 8,673.0 8,673.0 18:30 19:30 not hold air.Rack back stand,pull trip nipple and replace air boot.Tested good. Page 5/38 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) 074 CD5-18 ConocoN'taillips 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) 12/7/2016 12/8/2016 4.50 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 8,673.0 9,208.0 19:30 00:00 Intermediate hole from 8,673'MD to 9,208'MD,5,431'TVD.ADT=3.29 hrs. P/U=198k,S/0=147k,ROT=171k.830 gpm,2930 psi, 11.10 ppg ECD, 150 rpm,Tq on/off= 18.5k/10k. 12/8/2016 12/8/2016 12.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 9,208.0 10,885.0 00:00 12:00 Intermediate hole from 9,208'MD to 10,885'MD,6,190'TVD.ADT=8.83 hrs.P/U=235k,S/0=155k,ROT=187k. 830 gpm,3150 psi, 11.13 ppg ECD, 150 rpm,Tq on/off=23k/16k. 12/8/2016 12/8/2016 10.75 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 10,885.0 12,161.0 12:00 22:45 Intermediate hole from 10,885'MD to 12,161'MD,6,792'TVD.ADT=7.37 hrs.P/U=275k,S/0=152k, ROT=195k. 830 gpm,3460 psi, 11.23 ppg ECD, 150 rpm,Tq on/off=27.5k/15k. Change shaker screens to API 140 due stripping shale stabilizers,losing mud over shakers. Troubleshoot harmonics in MWD signal,change pump rates and data rates to stay in sync. 12/8/2016 12/9/2016 1.25 INTRM1 DRILL CIRC P Circulate 2 bottoms up,750-830 gpm, 12,161.0 12,161.0 22:45 00:00 2850-3310 psi, 140 rpm, 18-20.5k Tq. 12/9/2016 12/9/2016 1.00 INTRM1 DRILL CIRC P Continue circulate 2 bottoms up,750- 12,161.0 12,115.0 00:00 01:00 830 gpm,2850-3310 psi, 140 rpm, 18- 20.5k Tq.Rack back stand to 12115'. Mode switch MWD for better signal. 12/9/2016 12/9/2016 0.25 INTRM1 DRILL OWFF P Observe well for flow,static. 12,115.0 12,115.0 01:00 01:15 12/9/2016 12/9/2016 0.50 INTRM1 DRILL MPDA P Pull trip nipple and install RCD 12,115.0 12,115.0 01:15 01:45 element. 12/9/2016 12/9/2016 0.25 INTRM1 DRILL MPDA P Wash ream down from 12,115'MD to 12,115.0 12,161.0 01:45 02:00 12,161'MD,break in bearing MPD bearing.830 gpm,3090 psi,50-150 rpm, 16k tq. 12/9/2016 12/9/2016 10.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 12,161.0 13,310.0 02:00 12:00 Intermediate hole from 12,161'MD to 13,310'MD,7,311'TVD.ADT=7.09 hrs.P/U=285k,S/0=165k, ROT=202k. 830 gpm,3850 psi,11.65 ppg ECD, 170 rpm,Tq on/off=23k/19.5k. Holding 340 psi annular pressure on connections for 11.5 ESD. Weight up mud to 10.3 ppg on the fly prior to HRZ. Obtain SPR's holding annular pressure to maintain 11.5 ppg EMW ECD,250/210 psi at 30/40 rpm. Page 6/38 Report Printed: 1/24/2017 !perations Summary (with Timelog 6epths) CD5-18 ConocoPh illips RtrAa Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/9/2016 12/9/2016 10.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 13,310.0 14,144.0 12:00 22:00 Intermediate hole from 13,310'MD to 14,144'MD,7,520'TVD.P/U=300k, ROT=200k.830 gpm,4060 psi, 11.7 ppg ECD, 170 rpm,Tq on/off= 30k/28k.Holding 340 psi annular pressure on connections for 11.5 ESD. Obtain SPR's holding annular pressure to maintain 11.5 ppg EMW ECD,270/240 psi at 30/40 rpm. 12/9/2016 12/9/2016 1.25 INTRM1 DRILL RGRP T Change out liner/swab on mud pump 14,144.0 14,144.0 22:00 23:15 #1.Circulate 438 gpm 1450 psi with pump#2,80 rpm 23k Tq. 12/9/2016 12/10/2016 0.75 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 14,144.0 14,177.0 23:15 00:00 Intermediate hole from 14,144'MD to 14,177'MD,7,522'TVD.ADT=7.22 hrs.P/U=300k,ROT=200k.830 gpm, 4060 psi, 11.7 ppg ECD, 170 rpm,Tq on/off=30k/28k. 12/10/2016 12/10/2016 11.25 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 14,177.0 15,148.0 00:00 11:15 Intermediate hole from 14,177'MD to 15,148'MD,7,618'TVD.ADT=7.46, P/U=300k,S/0=150k,ROT=202k.830 gpm,4200 psi, 11.66 ppg ECD, 170 rpm,Tq on/off=33k/24k. Holding 340 psi annular pressure on connections for 11.5 ESD. Obtain SPR's holding annular pressure to maintain 11.5 ppg EMW ECD,280/240 psi at 30/40 rpm. 12/10/2016 12/10/2016 0.50 INTRM1 DRILL SVRG P Service rig,while working on#1 pump 15,148.0 15,148.0 11:15 11:45 swab/liner.C&C with pump#2 400 gpm, 1340 psi, 100 rpm,26k Tq. 12/10/2016 12/10/2016 0.25 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 15,148.0 15,168.0 11:45 12:00 Intermediate hole from 15,148'MD to 15,168'MD,7,618'TVD.ADT=.19, P/U=300k,S/0=150k,ROT=202k.830 gpm,4200 psi, 11.66 ppg ECD, 170 rpm,Tq on/off=33k/24k.Holding 340 psi annular pressure on connections for 11.5 ESD. 12/10/2016 12/10/2016 1.25 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 15,168.0 15,263.0 12:00 13:15 Intermediate hole from 15,168'MD to section TD, 15,263'MD,7,624'TVD. ADT=.91,P/U=300k,S/0=150k, ROT=202k.830 gpm,4200 psi, 11.66 ppg ECD, 170 rpm,Tq on/off= 33k/24k.Holding 340 psi annular pressure on connections for 11.5 ESD. Page 7/38 Report Printed: 1/24/2017 Aerations Summary (with Timelogpths) CD5-18 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time. End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/10/2016 12/10/2016 4.25 INTRM1 CASING CIRC P Circulate 3.5 bottoms up,830-850 15,263.0 15,207.0 13:15 17:30 gpm,4060-3580 psi.Pumped Nut Plug 11.5 ppg sweep @ 2 BU. Observe pump pressure loss from 4200-3850 psi with corresponding reduction in turbine rpm(3007-2850). Rck back stand and observe no float action,drill pipe in communication with annulus during MPD connection. 12/10/2016 12/10/2016 0.50 INTRMI CASING SEQP T Check surface equipment for washout, 15,207.0 15,207.0 17:30 18:00 check/clean MP suction screeens. 12/10/2016 12/10/2016 1.25 INTRM1 CASING CIRC T Circulate 800-700 gpm,3580-3090 psi 15,207.0 15,207.0 18:00 19:15 and observe pressure/TRPM still reducing slightly.60 rpm,22k. 12/10/2016 12/10/2016 1.25 INTRM1 CASING CIRC T Obtain parameters with reamer open, 15,207.0 15,207.0 19:15 20:30 700 gpm,2460 psi, 100 rpm,24.3 Tq, 1875 TRPM.P/U=275k,S/0=145k, ROT=205k. M/U TIW valve and single as ball launcher. Insert 1.625"ball on top closed TIW(due pipe overflowing.). M/U to string,open TIW and pump down ball to close reamer @ 250 gpm,reduce to 150 gpm. Observe ball seat @ 3300 strokes (15%over calc)Observe shear @ 2260 psi.Obtain reamer closed parameters 700 gpm,2280 psi, 100 rpm,22.8k, 1992 TRPM. 12/10/2016 12/11/2016 3.50 INTRM1 CASING CIRC T Circulate @ 350-300 gpm holding 200 15,207.0 15,207.0 20:30 00:00 -60 psi annular pressure as per schedule while weighting up from 10.3 ppg to 10.65 ppg.300 gpm,768 psi stable with 200 psi annular pressure, reduce AP to 60 psi,300 gpm 624 psi stable. 12/11/2016 12/11/2016 0.50 INTRM1 CASING CIRC T Continue circulate and weight up 15,207.0 15,241.0 00:00 00:30 system to 10.65 ppg,300 gpm,540 psi,60 rpm 23k Tq,holding 60 psi AP with MPD. 10.65 in/out at 15,000 stks. Observed weighted mud back early due washout. 12/11/2016 12/11/2016 3.50 INTRMI CASING CIRC T Continue circulate and weight up 15,241.0 15,241.0 00:30 04:00 system to 11.0 ppg,300 gpm 540 psi start,reduce to 150 gpm 290 with 60 psi annular pressure. SIMOPS-change out top drive blower motor for DS traction motor.Also change out all three screen rubber boots on shaker#1. 12/11/2016 12/11/2016 4.25 INTRM1 CASING CIRC T Continue circulate and weight up 15,241.0 15,241.0 04:00 08:15 system to 11.0 ppg, 150 gpm 290 with 60 psi annular pressure,reduce to 240 psi with 0 annular pressure. Pumped total 16,900 stks. 11#in/out. Obtain SPR's,(with wash out joint in hole).P/U=310k,S/0=155k. 12/11/2016 12/11/2016 0.25 INTRM1 CASING OWFF T Observe well for flow,static. 15,241.0 15,241.0 08:15 08:30 Page 8/38 Report Printed: 1/24/2017 .., - og •erations Summary (with Timelog 6epths) CD5-18 COMX.CWhillipS 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) 12/11/2016 12/11/2016 1.75 INTRM1 CASING PMPO T Pump out from 15,241'MD to 14,646' 15,241.0 14,646.0 08:30 10:15 MD @ 3 bpm, 190-140 psi.Found washout on joint 148.2"4"down from box end connection on botttom joint. 12/11/2016 12/11/2016 0.25 INTRM1 CASING PULD T Swap out washed out joint,marked 14,646.0 14,646.0 10:15 10:30 and laid down.P/U new joint,(-.2')and rack back stand. 12/11/2016 12/11/2016 1.50 INTRM1 CASING CIRC P Circulate and condition 200-450 gpm, 14,646.0 14,646.0 10:30 12:00 630-1690 psi,60 rpm, 19.5k Tq.Even out mud weight 11 ppg in/out.Got MWD @ 385 gpm,maintaining 11.8 ECD. 12/11/2016 12/11/2016 2.00 INTRM1 CASING CIRC P Continue CBU 450-430 gpm, 1700- 14,646.0 14,552.0 12:00 14:00 1660 psi, 100 rpm,24.5-21.5k Tq, rack back stand to 14,552'MD. Maintaining 11.8 ppg ECD. 12/11/2016 12/11/2016 1.00 INTRM1 CASING CIRC P Continue CBU 450-420 gpm, 1700- 14,552.0 14,521.0 14:00 15:00 1660 psi, 100 rpm,21.5k Tq, Maintaining 11.8 ppg ECD.Total circulated 2 bottoms up after washout joint dropped. 12/11/2016 12/11/2016 0.50 INTRM1 CASING MPDA P Blow down top drive,line up to 14,521.0 14,521.0 15:00 15:30 observe well,static. Line up MPD to SOON. 12/11/2016 12/11/2016 1.25 INTRM1 CASING SMPD P Strip out with MPD from 14,521'MD, 14,521.0 13,915.0 15:30 16:45 tight spot at 14,493'35k overpull.P/U single to S/O and break over. Continue pulling to 13,915'and pulled tight,35k-50k over staging up and breaking over. 12/11/2016 12/11/2016 1.50 INTRM1 CASING CIRC T M/U stand from derrick,circulate 390 13,915.0 13,990.0 16:45 18:15 gpm, 1490 psi,60 rpm,20.5k @ 13,990'-14,084'MD.Rack stand back in derrick,line up to BROOH. 12/11/2016 12/12/2016 5.75 INTRM1 CASING BKRM P Backream out of hole from 13,990'MD 13,990.0 13,165.0 18:15 00:00 to 13,165'MD @ 380-400 gpm, 1400- 1490 psi, 100 rpm 21-22k Tq, maintaining 11.8 max ECD.Start pulling 100 fph,able to increase to —400 fph. 12/12/2016 12/12/2016 12.00 INTRM1 CASING BKRM P Continue backreaming out of hole 13,165.0 10,417.0 00:00 12:00 from 13,165'MD to 10,417'MD.Start 400 gpm, 1400 psi,increase to 450 gpm 1560 psi, 100 rpm,20.5-14.5k Tq.Follow MPD ramp schedule on connections 200-150 annular pressure on connections to maintain 11.8 ppg ECD/ESD. P/U=240k,S/0=150k,ROT=182k 12/12/2016 12/12/2016 1.50 INTRM1 CASING BKRM P Continue backreaming out of hole 10,417.0 10,146.0 12:00 13:30 from 10,417'MD to 10,146'MD.450 gpm 1560 psi, 100 rpm,20.5-14.5k Tq.Follow MPD ramp schedule on connections holding 150 annular pressure on connections to maintain 11.8 ppg ECD/ESD. 12/12/2016 12/12/2016 1.50 INTRM1 CASING CIRC P Circulate to clean hole 1.5 bottoms up. 10,146.0 10,241.0 13:30 15:00 Increase rate from 450 gpm to 550 gpm maintain ing 11.8-11.9 ppg ECD. 1550-1930 psi, 100 rpm, 14.7k Tq. Page 9/38 Report Printed: 1/24/2017 Operations Summary (with Timelog fpths) 00 CD5-18 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-TX Operation (ftKB) End Depth(ftKB) 12/12/2016 12/12/2016 1.00 INTRM1 CASING CIRC P Pump weighted NP sweep around 550 10,241.0 10,241.0 15:00 16:00 gpm, 1930-2191 psi, 100-150 rpm, 14.3-16k Tq. 12/12/2016 12/13/2016 8.00 INTRM1 CASING BKRM P Continue backreaming out of hole 10,241.0 8,076.0 16:00 00:00 from 10,146 MD to 8,076'MD.550- 575 gpm 2090-2060 psi, 120 rpm, 20.2-18.2k Tq.Follow MPD ramp schedule on connections holding 150 annular pressure on connections to maintain 11.8 ppg ECD/ESD. 12/13/2016 12/13/2016 7.25 INTRM1 CASING BKRM T Continue backreaming out of hole 8,076.0 6,476.0 00:00 07:15 from 8,076'MD to 6,476'MD.575-700 gpm 2020-2800 psi, 120 rpm, 12- 10.5k Tq.Follow MPD ramp schedule on connections holding 150 annular pressure on connections to maintain 11.8 ppg ECD/ESD. 12/13/2016 12/13/2016 2.00 INTRM1 CASING CIRC P Circulate 2 BU stage rate up from 700 6,476.0 6,476.0 07:15 09:15 gpm to 830 gpm,2590-3540 psi. Pump 35 bbl 12.5 ppg HV NP sweep around followed by another BU maintaining 11.8 ECD throughout. P/U=170k,5/0=130k with pumps. SIMOPS-PJSM on pull RCD,install trip nipple. 12/13/2016 12/13/2016 0.25 INTRM1 CASING OWFF P Line up MPD to observe well for flow- 6,476.0 6,476.0 09:15 09:30 static.SIMOPS-Blow down top drive. 12/13/2016 12/13/2016 0.75 INTRM1 CASING MPDA P Blow down MPDE and pull RCD 6,476.0 6,476.0 09:30 10:15 element. Install trip nipple.Continue to observe well static. 12/13/2016 12/13/2016 1.75 INTRM1 CASING BKRM T Backream out of hole from 6,476'to 6,476.0 5,775.0 10:15 12:00 5,775'MD @ 800 gpm,3350-3270 psi, 120 rpm,7.5k Tq.Observing large clay returns. 12/13/2016 12/14/2016 12.00 INTRM1 CASING BKRM T Continue backreaming out of hole 5,775.0 3,334.0 12:00 00:00 from 5,775'to 3,334'MD @ 800 gpm, 3220-3010 psi, 120 rpm,5k Tq. Observing large clay returns, diminishing at—4,100'.Pumped HVHDNP sweep 12.5 ppg @ 4,200'. Performed 240 bbl whole mud 11.0 ppg dilution @ 3,650'due high MBT. Seeing large clay returns again. P/U=140k,5/0=118k,ROT=125k. 12/14/2016 12/14/2016 3.75 INTRM1 CASING BKRM T Continue backreaming out of hole 3,334.0 2,329.0 00:00 03:45 from 3,334'to 2,329'MD @ 800 gpm, 3010-2920 psi, 120 rpm,4k Tq. Observing large clay returns.Slow rotary as stabs and bit enter casing shoe.Observed slight packoffs(30 psi)with bit 25'from shoe. 12/14/2016 12/14/2016 0.50 INTRM1 CASING CIRC T Establish circulation 800 gpm,2920 2,329.0 2,329.0 03:45 04:15 psi, 150 rpm,2.5-3k Tq.Pump 35 bbl HVHDNP sweep 12.5 ppg around followed by another bottoms up.Good clay returns throughout and after sweep,shakers cleaned up. 12/14/2016 12/14/2016 0.25 INTRM1 CASING OWFF T Observe well for flow,static and 2,329.0 2,329.0 04:15 04:30 dropping slightly. Page 10/38 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) - , CD5-18 ooPnntuiips ' 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) 12/14/2016 12/14/2016 1.75 INTRM1 CASING PMPO T Pump out of hole from 2,329'MD to 2,329.0 823.0 04:30 06:15 823'MD(HWDP),500 gpm, 1020 psi. OWFF static,PJSM on L/D BHA. 12/14/2016 12/14/2016 1.00 INTRM1 CASING PMPO T Continue pumping out @ 500 gpm 823.0 272.0 06:15 07:15 980 psi from 823'MD to 272'MD BHA. 12/14/2016 12/14/2016 1.75 INTRM1 CASING BHAH T POOH on trip tank,lay down BHA#2 272.0 0.0 07:15 09:00 per SLB DD.Total trip Calc fill=138 bbl,Actual Fill=344 bbl. 12/14/2016 12/14/2016 1.25 INTRM1 CASING WWWH P Clean and clear rig floor, Function 0.0 0.0 09:00 10:15 rams, M/U stack washer and flush stack with 600-700 gpm,340-380 psi. 20 rpm, .5k Tq.Lay down stack washer,drain stack and pull wear ring. 12/14/2016 12/14/2016 0.75 INTRM1 CASING BOPE P Change out 3-1/2"x 6"VBR to 7-5/8" 0.0 0.0 10:15 11:00 SBR.SIMOPS-=R/U Volant CRT, pick up bail extensions via beaverslide 12/14/2016 12/14/2016 1.00 INTRMI CASING BOPE P Set 7-5/8"test joint,fill stack with 0.0 0.0 11:00 12:00 water.Test annular to 250/2500 psi 5 min each. 12/14/2016 12/14/2016 0.25 INTRM1 CASING BOPE P Test 7-5/8"UPR to 250/3500 psi 5 min 0.0 0.0 12:00 12:15 each.R/D test equipment. 12/14/2016 12/14/2016 0.50 INTRM1 CASING BOPE P Pull test joint and set thin wall wear 0.0 0.0 12:15 12:45 ring per FMC rep. 10.375"ID. 12/14/2016 12/14/2016 0.75 INTRM1 CASING RURD P R/U casing equipment,bail 0.0 0.0 12:45 13:30 extensions,350 ton slips,casing elevators. 12/14/2016 12/15/2016 10.50 INTRM1 CASING PUTB 'P PJSM, P/U and and run 7-5/8"29.7#L 0.0 3,859.0 13:30 00:00 -80 BTCM casing.Made up shoe,float collar,baffle collar and BL joints, establish circulation and checked floats OK.Continue running casing to 3,859'MD,torquing BTCM connections @ 10.4k to the mark. S/0=120k @ 3,859'. 12/15/2016 12/15/2016 3.75 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 3,859.0 6,341.0 00:00 03:45 BTCM casing from 3,859 MD to 6,341' MD,torquing BTCM connections @ 10.4k to the mark. P/U=180k,S/0=145k pumping.5 bpm. 12/15/2016 12/15/2016 2.00 INTRM1 CASING CIRC P Establish circulation and stage up 6,341.0 6,341.0 03:45 05:45 from .7 bpm to 5 bpm,220-260 psi. Circulate 1 bottoms up while reciprocating pipe 3400 stks.Heaviest mud returns observed 11.1+ppg. 12/15/2016 12/15/2016 6.25 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 6,341.0 9,419.0 05:45 12:00 BTCM casing from 6,341'MD to 9,419'MD,torquing BTCM connections @ 10.4k to the mark. Made up stage collar @ 8,900'MD, BakerLock'd and torqued to 11.8k. Verified six shear screws installed. 5/0=162k @ 9,419'MD. 12/15/2016 12/15/2016 2.25 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 9,419.0 10,096.0 12:00 14:15 BTCM casing from 9,419'MD to 10,096'MD,torquing BTCM connections @ 10.4k to the mark. P/U=275k,S/0=165k. Page 11/38 Report Printed: 1/24/2017 R Ng • Operations Summary (with Timelog Depths) CD5-18 Cor►ocoPhillips 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) 12/15/2016 12/15/2016 3.25 INTRM1 CASING CIRC P Establish circulation and stage up 10,096.0 10,137.0 14:15 17:30 from.5 bpm to 5 bpm,290-390 psi. Circulate 1 bottoms up while reciprocating pipe 6580 stks.P/U=275 -250k,S/0=165-160k.Heaviest mud returns observed 11.2+ppg. 12/15/2016 12/16/2016 6.50 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 10,137.0 12,173.0 17:30 00:00 BTCM casing from 10,137'MD to 12,173'MD,torquing BTCM connections @ 10.4k to the mark. S/0=175k @ 12,173'MD. 12/16/2016 12/16/2016 1.50 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 12,173.0 12,567.0 00:00 01:30 BTCM casing from 12,173'MD to 12,567'MD,torquing BTCM connections @ 10.4k to the mark. S/0=182k @ 12,567'MD. 12/16/2016 12/16/2016 4.50 INTRM1 CASING CIRC P Establish circulation and stage up 12,567.0 12,567.0 01:30 06:00 from.5 bpm to 4 bpm,350-490 psi. Circulate 1 bottoms up while reciprocating pipe 7800 stks.P/U=310 -290k,S/0=175k.Heaviest mud returns observed 11.3 ppg. 12/16/2016 12/16/2016 6.00 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 12,567.0 14,550.0 06:00 12:00 BTCM casing from 12,567'MD to 12,809'MD,P/U XO Jt to H563, continue running Hydril 563 to 14,550' MD torquing H563 dopeless connections @ 12.4k. S/0=150k @ 14,550'MD. 12/16/2016 12/16/2016 2.75 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 14,550.0 15,215.0 12:00 14:45 H563 casing from 14,550'MD to 15,215'MD,torquing H563 dopeless connections @ 12.4k. S/0=150k @ 15,215'MD. 12/16/2016 12/16/2016 0.25 INTRM1 CASING HOSO P Make up 7-5/8"FMC casing hanger 15,215.0 15,251.0 14:45 15:00 and landing joint,slack off and land hanger @ 15,251'MD. 12/16/2016 12/16/2016 6.50 INTRM1 CEMENT CIRC P Establish circulation and stage up 15,251.0 15,251.0 15:00 21:30 from .5 bpm to 8 bpm,500-600 psi, max mud weight out 11.3 ppg,stage up to 8 bpm as mud weight fell to 11.0 ppg.Circulate 2.5 bottoms up conditioning mud for cement job per program. 12/16/2016 12/16/2016 0.50 INTRM1 CEMENT RURD P Shut down,R/U and blow down top 15,251.0 15,251.0 21:30 22:00 drive.Close auto and manual IBOP. R/U cement line to Volant CRT. 12/16/2016 12/16/2016 0.50 INTRM1 CEMENT CIRC P Establish circulation @ 8 bpm 600 psi 15,251.0 15,251.0 22:00 22:30 via cement line. SIMOPS-PJSM on cement job. 12/16/2016 12/16/2016 0.25 INTRM1 CEMENT OWFF P Shut down and observe well for flow, 15,251.0 15,251.0 22:30 22:45 static 10 min. Page 12/38 Report Printed: 1/24/2017 �erations Summary (with Timelog Depths) i4 CD5-18 +Conousphitliips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/16/2016 12/17/2016 1.25 INTRM1 CEMENT CMNT P SLB flood lines with 2 bbl water and 15,251.0 15,251.0 22:45 00:00 pressure test to 4000 psi-good.Bleed off pressure.SLB pumped 43.6 bbl of 12.5 ppg MudPush II spacer.Shut down and load bottom(bypass)plug. SLB mix and begin pumping 15.8 ppg Class G Qannik Slurry @ 4 bpm, 100 psi SPP. 100 bbl pumped @ 24:00 hr with full returns. S/D @ 54 bbl away due leaking Volant cup.Shut down and pulled to change cup,found piece of Buna rubber from bypass plug had caught between Volant stabbing guide and cup,tearing off—40%of the top fin of the bypass plug.Retrieved the rubber,re-stab Volant and resumed cementing and displacement.Total pumps off time 4 minutes. 12/17/2016 12/17/2016 2.50 INTRM1 CEMENT CMNT P Continue pumping stage 1 cement job. 15,251.0 15,251.0 00:00 02:30 SLB pumped total 215.7 bbl of 15.8 ppg Class G Qannik slurry @ 4 bpm, 110 psi SPP.Load and drop top plug, SLB kick out plug with 10.3 bbl H20. Rig displace cement with 11.0 ppg LSND @ 8 bpm,320-1120 psi. Slowed rate to 3 bpm as plugs pass stage collar and prior to bump. Bumped plug @ 6846 stks 750 psi. Pressure up to 1300 psi and hold 5 min.Bleed off and check floats- Good. 12/17/2016 12/17/2016 1.25 INTRM1 CEMENT CIRC P Pressure up to 3100 psi,shift open 15,251.0 6,350.0 02:30 03:45 stage collar @ 6,350'MD per HES rep.CBU stage pumps up to 8 bpm 540 psi,maintain MW 11.0 ppg in/out. SIMOPS-PJSM on stage 2 cement job. Shut down,OWFF static. 12/17/2016 12/17/2016 2.00 INTRM1 CEMENT CMNT P Flood lines,SLB mix and pump 43.1 6,350.0 0.0 03:45 05:45 bbl 12.5 ppg MudPush II 3.3 bpm 240 psi.Follow with 57.6 bbl 15.8 ppg Class G Qannik slurry 3.1 bpm 135 psi.Shut down and load closing plug. SLB kicked out plug with 10 bbl H20. Rig displaced cement with 11.0 ppg LSND @ 8 bpm,slowed to 3 bpm 370 psi to bump plug @ 2815 stks. Pressure up to 2000 psi,observe stage tool shift @—1800 psi.Continue pressure up to 3300 psi and hold 5 minutes to ensure stage tool is closed. 12/17/2016 12/17/2016 0.50 INTRM1 CEMENT RURD P Blow down lines,rig down cement 0.0 0.0 05:45 06:15 lines.Lay down landing joint. 12/17/2016 12/17/2016 1.25 INTRM1 CEMENT WWSP P Make up wear ring retrieval tool, 0.0 0.0 06:15 07:30 retrieve same.M/U packoff to running tool,set packoff per FMC rep.Test packoff to 5000 psi for 10 minutes CPAI witnessed.Lay down running tool. Page 13/38 Report Printed: 1/24/2017 Operations Summary (with Timelog 6epths) F e CD5-18 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/17/2016 12/17/2016 1.00 INTRM1 CEMENT RURD P Rig down Volant CRT.Lay down via 0.0 0.0 07:30 08:30 Beaver slide. Inspect top drive, remove skate roller. 12/17/2016 12/17/2016 3.50 INTRMI CEMENT PULD P Lay down 28 stands 5"DS50 drill pipe 0.0 0.0 08:30 12:00 via 90'mousehole. SIMOPS-Change out Upper pipe rams from 7-5/8"SBR to 3-1/2"x 6" VBR. 12/17/2016 12/18/2016 12.00 INTRMI CEMENT PULD P Lay down 22 stands 5"DS50,20 jts 5" 0.0 0.0 12:00 00:00 HWDP,Jars and 90 stands 5"NC50 via 9"mousehole. SIMOPS-GIS perform annular LOT (16.2 ppg),annular flush 300 bbl H2O 3 bpm 550 psi and freeze protect with 84 bbl diesel @ 2 bpm 653 psi. Shut in annulus @ 20:00 hrs. OA pressure @ 22:00 hrs=700 psi. 12/18/2016 12/18/2016 2.00 INTRM1 CEMENT PULD P Continue laying down 5"NC50 drill 0.0 0.0 00:00 02:00 pipe, 14 stands. 12/18/2016 12/18/2016 0.75 INTRM1 CEMENT RURD P Change out 5"elevators to 4". Install 0.0 0.0 02:00 02:45 roller on rig floor ramp for skate. Bring up BHA components,P/U 4"pup joint. 12/18/2016 12/18/2016 1.75 INTRM1 CEMENT RURD P PJSM,Change out saver sub to XT- 0.0 0.0' 02:45 04:30 39.Change out bell guides for 4"DP. 12/18/2016 12/18/2016 1.00 INTRM1 CEMENT SLPC P PJSM,slip/cut 83'of drilling line. 0.0 0.0 04:30 05:30 12/18/2016 12/18/2016 0.50 INTRM1 CEMENT SVRG P Service rig,top drive,draworks and 0.0 0.0 05:30 06:00 blocks. 12/18/2016 12/18/2016 1.00 INTRM1 WHDBOP RURD P M/U 4"test joint to test plug and set. 0.0 0.0 06:00 07:00 M/U 4"XT-39 TIW valve and Dart valve to XO. 12/18/2016 12/18/2016 2.00 INTRM1 WHDBOP RURD P R/U hoses,gauges,chart recorder 0.0 0.0 07:00 09:00 and equipment for testing.Fill stack, choke manifold and kill line with water, purge air from system. 12/18/2016 12/18/2016 0.50 INTRMI WHDBOP BOPE P Test annular preventer with 4"Test 0.0 0.0 09:00 09:30 joint to 250/2500 psi 5 min ea. AOGCC Chuck Scheve waived witness. 12/18/2016 12/18/2016 2.50 INTRM1 WHDBOP BOPE P Test with 4"test joint upper 3%"x 6" 0.0 0.0 09:30 12:00 VBR's,Choke valves 1, 12,13,14, Auto IBOP,4"Kill line Demco,Choke valves 9, 11,Manual IBOP,HCR kill, needle valve above 1,Choke valves 5, 8, 10,4"XT-39 Dart valve,Choke valves 4,6,7,XT-39 FOSV,Valve 2, HCR choke.All tests to 250/3500 psi for 5 min ea on chart. 12/18/2016 12/18/2016 1.00 INTRMI WHDBOP BOPE P Continue testing with 4"test joint,test 0.0 0.0 12:00 13:00 manual choke/kill,lower 3'/2'x 6" VBR's. 12/18/2016 12/18/2016 0.25 INTRM1 WHDBOP BOPE P Perform accumulator test.System 0.0 0.0 13:00 13:15 pressure=3000 psi,Pressure after closing=1600 psi,200 psi attained=22 sec,Full system recovery=121 sec.4 bottle N2 average=2000 psi.Function with remote panels. Page 14/38 Report Printed: 1/24/2017 • Operations Summary (with TimelogDpths) Oi 0 CD5-18 ConocoPhillips Az.aa Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 12/18/2016 12/18/2016 0.50 INTRM1 WHDBOP BOPE P Test blind rams 250/3500 psi.Test 0.0 0.0 13:15 13:45 manual and super auto choke to 1100 psi. 12/18/2016 12/18/2016 1.50 INTRM1 WHDBOP BOPE P Change out to 4'W test joint.Test 0.0 0.0 13:45 15:15 annular to 250/2500 psi,Choke valve #3,upper and lower VBR's to 250/3500 psi.Tested gas alarms, function flow meter,PVT and all alarms. 12/18/2016 12/18/2016 1.00 INTRM1 WHDBOP RURD P Rig down test lines,pull test plug. 0.0 0.0 15:15 16:15 Install wear ring per FMC.(ID=7.125", OD=10.75",Length=21.75"). SIMOPS-Install new bolts on bell guide and safety wire.Grease!BOP. 12/18/2016 12/18/2016 2.25 INTRM1 CEMENT BHAH P PJSM,M/U BHA#3 per SLB 0.0 338.0 16:15 18:30 DD/MWD to 338'MD. 12/18/2016 12/18/2016 1.75 INTRM1 CEMENT PULD P Single in hole with BHA#3 with 4"14# 338.0 1,660.0 18:30 20:15 XT-39 drill pipe from pipe shed 338' MD to 1,660'MD. 12/18/2016 12/18/2016 0.50 INTRM1 CEMENT DHEQ P Kelly up,establish circulation and 1,660.0 1,660.0 20:15 20:45 shallow pulse test MWD @ 220 gpm, 1600 psi.Tools good. 12/18/2016 12/19/2016 3.25 INTRM1 CEMENT PULD P Single in hole with BHA#3 with 4"14# 1,660.0 4,000.0 20:45 00:00 XT-39 drill pipe from pipe shed 1,660' MD to 4,000'MD. OA pressure©22:00 hrs=600 psi 12/19/2016 12/19/2016 3.25 INTRM1 'CEMENT PULD P Single in hole with BHA#3 with 4"14# 4,000.0 6,268.0 00:00 03:15 XT-39 drill pipe from pipe shed 4,000' MD to 6,268'MD,took 10k down weight.P/U to 6,262'to wash/ream down. 12/19/2016 12/19/2016 0.25 INTRM1 CEMENT CIRC P OWFF,establish circulation and 6,268.0 6,268.0 03:15 03:30 obtain SPR's. 12/19/2016 12/19/2016 0.75 INTRM1 CEMENT COCF P Wash and ream down to top of stage 6,268.0 6,350.0 03:30 04:15 collar,6,268'MD to 6,350'MD 200 gpm, 1860 psi,60 rpm,6k Tq. Observed string weight and torque from 6,268'MD to 6,272'MD.Also observed plug rubber on shakers @ bottoms up from 6,268'MD.Tagged stage collar on depth @ 6,350'MD.. 12/19/2016 12/19/2016 0.25 INTRM1 CEMENT DRLG P Drill out stage collar from 6,350'MD to 6,350.0 6,353.0 04:15 04:30 6,353'MD @ 160 gpm, 1330 psi,60 rpm 7k Tq.Observing plug rubber and cement on shakers. 12/19/2016 12/19/2016 1.75 INTRM1 CEMENT REAM P Wash and ream from 6,353'MD to 6,353.0 6,663.0 04:30 06:15 6,663'MD 200-230 gpm, 1840-2140 psi,60 rpm,6.5k Tq. P/U=142k, S/O=95k. 12/19/2016 12/19/2016 0.75 INTRM1 CEMENT PRTS P Test casing to verify stage collar 6,663.0 6,663.0 06:15 07:00 integrity 3500 psi for 10 minutes charted.Tested good,bleed off pressure,blow down kill line,rig down test equipment. 12/19/2016 12/19/2016 2.25 INTRM1 CEMENT PULD P Continue single in hole with BHA#3 6,663.0 8,546.0 07:00 09:15 with 4"14#XT-39 drill pipe from pipe shed 6,663'MD to 8,546'MD, S/O=95k. Page 15/38 Report Printed: 1/24/2017 • Operations Summary (with Timelog 6epths) CD5-18 i ric coPhitilps _y Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/19/2016 12/19/2016 0.75 INTRM1 CEMENT QEVL P Establish circulation,downlink to 8,546.0 8,546.0 09:15 10:00 activate Sonicscope 230 gpm 2400 psi.P/U to 8,452'MD,log down to 8,546'MD @ 900 fph for free ring signature behind pipe. 12/19/2016 12/19/2016 0.50 INTRM1 CEMENT SVRG P Service top drive and blocks. 8,546.0 8,546.0 10:00 10:30 12/19/2016 12/19/2016 1.50 INTRM1 CEMENT PULD P Continue single in hole with BHA#3 8,546.0 9,777.0 10:30 12:00 with 4"14#XT-39 drill pipe from pipe shed 8,546'MD to 9,777'MD, P/U=190k,S/0=100k,fill pipe every 20 stands. OA pressure @ 11:00 hrs=440 psi 12/19/2016 12/19/2016 1.50 INTRM1 CEMENT PULD P Continue single in hole with BHA#3 9,777.0 10,978.0 12:00 13:30 with 4"14#XT-39 drill pipe from pipe shed 9,777'MD to 10,978'MD, P/U=195k,S/0=103k,fill pipe every 20 stands. 12/19/2016 12/19/2016 1.00 INTRM1 CEMENT QEVL P M/U top drive and pump 220 gpm 10,978.0 11,105.0 13:30 14:30 2420 psi,downlink to activate Sonicscope.P/U DP and RIH @ 900 fph Sonic log from 10,978'to 11,105' MD.Downlink to verify data is recording,220 gpm,2360 psi. 12/19/2016 12/19/2016 5.00 INTRM1 CEMENT QEVL P Continue Sonic Log @ 900 fph from 11,105.0 13,285.0 14:30 19:30 11,105'MD to 13,285'MD with Sonicscope in recorded mode,picking up 4"DP from pipe shed. 12/19/2016 12/19/2016 0.75 INTRMI CEMENT QEVL P Real time log with Impulse Gamma @ 13,285.0 13,377.0 19:30 20:15 150-200 fph to correlate formation Kuparuk C(-13,304'MD,7.5'deep compared to drilling log).230 gpm, 2740 psi.Continue recording Sonicscope data. 12/19/2016 12/19/2016 1.50 INTRM1 CEMENT QEVL P Continue Sonic Log @ 900 fph from 13,377.0 13,852.0 20:15 21:45 13,377'MD to 13,852'MD with Sonicscope in recorded mode,picking up 4"DP from pipe shed. 12/19/2016 12/19/2016 1.50 INTRM1 CEMENT DLOG P Real time log with Impulse Gamma @ 13,852.0 14,079.0 21:45 23:15 150-200 fph to locate PIP tag,230 gpm 2800 psi from 13,852'(Bit depth). Impulse identified PIP tag(361 gAPI) @ 13,853.5'(Impulse depth(61.42' offest))with no rotation.P/U,establish 80 rpm rotation and repeat pass. Impulse identified PIP tag @ 13,849' MD with rotation.Continue RIH to correlate formation Alpine C(-13,990' MD,8'deep compared to drilling log). 230 gpm,2740 psi.Continue recording Sonicscope CBL data to 14,079'bit depth. 12/19/2016 12/20/2016 0.75 INTRM1 CEMENT QEVL P Continue Sonic Log @ 900 fph from 14,079.0 14,430.0 23:15 00:00 14,079'MD to 14,430'MD with Sonicscope in recorded mode,picking up 4"DP from pipe shed via 90' mousehole. OA pressure @ 22:00 hrs=300 psi. Page 16/38 Report Printed: 1/24/2017 0i. Operations Summary (with Timelog 6epths) 1 CD5-18 Coro. t hiillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/20/2016 12/20/2016 0.75 INTRM1 CEMENT QEVL P Continue Sonic Log @ 900 fph from 14,430.0 14,895.0 00:00 00:45 14,430'MD to 14,895'MD with Sonicscope in recorded mode,picking up 4"DP from pipe shed via 90' mousehole. 12/20/2016 12/20/2016 1.25 INTRM1 CEMENT CIRC P Rig up headpin,vlaves and sensors to 14,895.0 14,895.0 00:45 02:00 circulate down string and for casing test.Establish circulation and CBU @ 230 gpm 2850 psi conditioning mud from 11.0 ppg to 11.6 ppg. 12/20/2016 12/20/2016 2.50 INTRM1 CEMENT PRTS P Test surface lines to 3800 psi,good. 14,895.0 14,895.0 02:00 04:30 Bleed off pressure.Pressure test casing and annulus valves to 3500 psi.Observe pressure fluctuations due wind changing directions.Shut down and re-configure test manifold and lines.Re-test casing to 3500 psi for 30 minutes charted,good. 12/20/2016 12/20/2016 0.50 INTRM1 CEMENT COCF P Wash and ream f/14,895'to TOC @ 14,895.0 15,045.0 04:30 05:00 15,045'MD with 230-180 gpm,2850 psi,60 rpm,and 16.5k TQ. 12/20/2016 12/20/2016 4.25 INTRM1 CEMENT DRLG P Drill out shoe track f/15,045'to 15,045.0 15,251.0 05:00 09:15 15,251'MD with 180 gpm, 1950 psi, 40 rpm, 19.5k TQ,and 5-10k WOB. 12/20/2016 12/20/2016 0.50 INTRM1 CEMENT DRLG P Drill out rat hole f/15,251'to 15,263' 15,251.0 15,263.0 09:15 09:45 MD. 240 gpm,3130 psi,40 rpm, 19.5k TQ,5-10k WOB. 12/20/2016 12/20/2016 1.25 INTRM1 CEMENT DDRL P Drilled 20'of new formation f/15,263' 15,263.0 15,284.0 09:45 11:00 to 15,284'MD,7,635'TVD. 12/20/2016 12/20/2016 0.50 INTRM1 CEMENT REAM P Worked through shoe at 15,251'MD 15,284.0 15,181.0 11:00 11:30 with 240 gpm,2950 psi,50 rpm, 19.5k TQ. Rotation was required to pull through. Pulled in to casing at 15,181' MD. 12/20/2016 12/20/2016 1.25 INTRM1 CEMENT CIRC P Circulated and conditioned mud at 240 15,181.0 15,181.0 11:30 12:45 gpm,50 rpm,2590 psi. 12/20/2016 12/20/2016 1.25 INTRM1 CEMENT FIT P R/U test equipment and FIT to 12.5 15,181.0 15,181.0 12:45 14:00 ppg EMW with 10.4 ppg mud at 830 psi at surface. R/D test equipment. 12/20/2016 12/20/2016 0.25 PROD1 DRILL OWFF P OWFF,well static. 15,181.0 15,181.0 14:00 14:15 12/20/2016 12/20/2016 1.25 PROD1 DRILL MPDA P Removed trip nipple and installed 15,181.0 15,181.0 14:15 15:30 MPD elements. 12/20/2016 12/20/2016 1.00 PROD1 DRILL CIRC P Displace to 9 ppg FlowPro while RIH 15,181.0 15,284.0 15:30 16:30 at 240 gpm. 12/20/2016 12/21/2016 7.50 PROD1 DRILL DDRL P Drill f/15,284'to 16,070'MD,7,643' 15,284.0 16,070.0 16:30 00:00 TVD. 240 gpm,2160 psi, 140 rpm, 12.1k TQ, 15k WOB. P/U=200k, S/O=135k. 12/21/2016 12/21/2016 12.00 PROD1 DRILL DDRL P Drill f/16,070'to 17,818'MD,7,679' 16,070.0 17,818.0 00:00 12:00 TVD. 260 gpm,2700 psi, 140 rpm, 1l k TQ, 15k WOB. P/U=205k,S/0= 127k,ROT= 160k. 12/21/2016 12/22/2016 12.00 PROD1 DRILL DDRL P Drill f/17,818'to 19,561'MD,7,693' 17,818.0 19,561.0 12:00 00:00 TVD. 260 gpm,2970 psi, 140 rpm, 11.7k TQ, 15k WOB. P/U=200k, S/O=125k,ROT=165k. Page 17/38 Report Printed: 1/24/2017 . • • J 0Operations Summary (with Timelog Depths) I CD5-18 Conoccehillips 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) 12/22/2016 12/22/2016 12.00 PROD1 DRILL DDRL P Drill f/19,561'to 21,257'MD,7,714' 19,561.0 21,257.0 00:00 12:00 TVD. Started installing WWT Super Sliders from 20,802'MD and on. 260 gpm,3000 psi, 140 rpm, 12.6k TQ, 15k WOB. P/U=210k,S/O=122k, ROT=162k. 12/22/2016 12/23/2016 12.00 PROD1 DRILL DDRL P Drill f/21,257'to 22,820'MD,7,740' 21,257.0 22,820.0 12:00 00:00 TVD. 260 gpm,3110 psi, 140 rpm, 14.4k TQ, 15k WOB. P/U=220k, S/0= 120k,ROT=165k. 12/23/2016 12/23/2016 12.00 PROD1 DRILL DDRL P Drill f/22,820 to 24,421'MD,7,766' 22,820.0 24,421.0 00:00 12:00 TVD. 260 gpm,3490 psi, 140 rpm, 17.4k TQ, 16k WOB. P/U=235k, S/0=90k,ROT=175k. 12/23/2016 12/23/2016 7.75 PROD1 DRILL DDRL P Drill f/24,421 to 25,355'MD,7,778' 24,421.0 25,355.0 12:00 19:45 TVD. 260 gpm,3450 psi, 140 rpm, 17.5k TQ, 17k WOB. 12/23/2016 12/23/2016 2.25 PROD1 DRILL CIRC P Circulated BU to clean hole and 25,355.0 25,355.0 19:45 22:00 releave drilling parameters. 260 gpm, 3710-3510 psi,80-140 rpm, 18-14k TQ. 12/23/2016 12/24/2016 2.00 PROD1 DRILL DDRL P Drill f/25,355 to 25,564'MD,7,778' 25,355.0 25,564.0 22:00 00:00 TVD. 260 gpm,3440 psi, 140 rpm, 16k TQ, 16k WOB. P/U=233k,ROT= 162k. 12/24/2016 12/24/2016 11.75 PROD1 DRILL DDRL P Drill f/25,564'to TD at 27,089'MD, 25,564.0 27,089.0 00:00 11:45 7,807'TVD. 260 gpm,3590 psi, 140 rpm, 19.8k TQ, 17k WOB. P/U=233k, ROT=173k. 12/24/2016 12/24/2016 4.75 PROD1 CASING CIRC P Take final survey and circulate 2 BU at 27,089,0 26,900.0 11:45 16:30 220-260 gpm and 3810 psi while racking a stand back each BU. 120rpm, 15-18k Tq. 12/24/2016 12/24/2016 0.50 PROD1 CASING OWFF P Performed drawdown test. shut in 26,900.0 26,900.0 16:30 17:00 chokes for 8 min and saw pressure build to 16 psi. Opened chokes and bleed off 1/4 bbl. shut chokes again for 5 min and saw pressure build to 5 psi. pressured up the annulus to 200 psi to check string for wash outs, string held. 12/24/2016 12/24/2016 6.25 PROD1 CASING CIRC P Circulate 2 BU at 220-230 gpm,2830- 26,900.0 26,707.0 17:00 23:15 3150 psi, 100-120 rpm, 13-16k Tq. while racking back a stand each BU to 26707'MD. 12/24/2016 12/25/2016 0.75 PROD1 CASING DISP P Begin displacing mud to 9.4#viscous 26,707.0 26,707.0 23:15 00:00 brine at 205-230 gpm,2800-3320 psi, 100-110 rpm,and 12.5-14k Tq. 12/25/2016 12/25/2016 3.00 PROD1 CASING DISP P Displaced well to 9.4#viscosified brine 26,707.0 26,707.0 00:00 03:00 at 26,707'MD. 230 gpm,2700-2250 psi, 100-110 rpm, 12.5-10.5k Tq, P/U= 225,S/O= 125, ROT=170. 12/25/2016 12/25/2016 0.25 PROD1 CASING CIRC P Took SPR and B/D TD. 26,707.0 26,707.0 03:00 03:15 12/25/2016 12/25/2016 0.50 PROD1 CASING OWFF P OWFF for 30 min.Well Static. 26,707.0 26,707.0 03:15 03:45 12/25/2016 12/25/2016 2.75 PROD1 CASING BKRM P BROOH f/26,707'to 25,564'MD with 26,707.0 25,564.0 03:45 06:30 230 gpm,2100 psi, 100 rpm,and 11- 10.5k Tq. Page 18/38 Report Printed: 1/24/2017 • Operations Summary (with Timelog Depths) CD5-18 . ConocoPhitilps L Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/25/2016 12/25/2016 6.50 PROD1 CASING CIRC P Circulate 3 BU while rotating at 100 25,564.0 25,373.0 06:30 13:00 rpm,racking a stand back on each BU. 265 gpm,2710 psi, 11k Tq. 12/25/2016 12/25/2016 1.00 PROD1 CASING OWFF P OWFF,well static. took SPR and B/D 25,373.0 25,373.0 13:00 14:00 TD. mean while thawed out a frozen line from the cellar. 12/25/2016 12/25/2016 0.75 PROD1 CASING SMPD P SOOH f/25,373'to 24,670'MDwith 25,373.0 24,670.0 14:00 14:45 160 psi BP pulling and 30 psi in slips. A SS clamp was missing on stand# 257. 12/25/2016 12/25/2016 1.25 PROD1 CASING MPDA T Removed remaining clamps on stand 24,670.0 24,670.0 14:45 16:00 and removed RCD bearing. Missing SS clamp was found between the two elements once removed. Installed trip nipple. 12/25/2016 12/25/2016 6.25 PROD1 CASING TRIP P POOH on elevators f/24,670'to 24,670.0 20,703.0 16:00 22:15 20,703'MD. 12/25/2016 12/25/2016 0.75 PROD1 CASING MPDA P OWFF and removed trip nipple. 20,703.0 20,703.0 22:15 23:00 Installed new RCD element. 12/25/2016 12/26/2016 1.00 PROD1 CASING SMPD P SOOH f/20,703 to 19,834'MD while 20,703.0 19,834.0 23:00 00:00 holding 160/30 psi out/in slips. 12/26/2016 12/26/2016 3.50 PROD1 CASING SMPD P SOOH f/19,834'to 7 5/8"casing shoe 19,834.0 15,251.0 00:00 03:30 at 15,251'MD while holding 160/30 psi out/in slips. 12/26/2016 12/26/2016 0.50 PROD1 CASING REAM P Observed 10k overpull while passing 15,251.0 15,181.0 03:30 04:00 the shoe. established circulation and rotation and reamed tight spot clear. 260 gpm, 1800 psi, 100 rpm. 12/26/2016 12/26/2016 1.50 PROD1 CASING CIRC P Circulate BU at 260 gpm, 1870 psi, 15,181.0 15,181.0 04:00 05:30 100 rpm,5.3k Tq. P/U=185,S/O= 142,ROT=164. 12/26/2016 12/26/2016 0.50 PROD1 CASING OWFF P OWFF,well static. Pumped 29 bbl, 15,181.0 15,181.0 05:30 06:00 10.5 ppg dry job,B/D TD and dropped 2.11"hollow drift. 12/26/2016 12/26/2016 8.50 PROD1 CASING SMPD P SOOH f/15,181'to 998'MDholding 15,181.0 998.0 06:00 14:30 30/90 psi in/out of slips. 12/26/2016 12/26/2016 0.50 PROD1 CASING OWFF P OWFF,Well static. B/D TD. 998.0 998.0 14:30 15:00 12/26/2016 12/26/2016 0.50 PROD1 CASING MPDA P Removed RCD bearing and installed 998.0 998.0 15:00 15:30 trip nipple. 12/26/2016 12/26/2016 0.50 PROD1 CASING TRIP P POOH on elevators f/998'to 338'MD. 998.0 338.0 15:30 16:00 12/26/2016 12/26/2016 0.25 PROD1 CASING OWFF P OWFF,slight drop in fluid level. 338.0 338.0 16:00 16:15 12/26/2016 12/26/2016 2.00 PROD1 CASING BHAH P L/D 6 3/4"Production) BHA as per 338.0 0.0 16:15 18:15 SLB. Calculated fill for trip=146.6 bbl,Act.=266 bbl. Hollow drift recovered at top of jars. 12/26/2016 12/26/2016 1.25 COMPZ1 CASING RURD P Clean and clear rig floor,L/D tools and 0.0 0.0 18:15 19:30 equipment. P/U 4 1/2"liner running tools,tongs,and air slips. 12/26/2016 12/26/2016 0.50 COMPZ1 CASING SVRG P Service crown,TD,and draw works. 0.0 0.0 19:30 20:00 12/26/2016 12/27/2016 4.00 COMPZ1 CASING PUTB P RIH with 4 1/2"12.6#L80 TXP liner to 0.0 2,091.0 20:00 00:00 2,091'MD. 12/27/2016 12/27/2016 13.25 COMPZ1 CASING PUTB P RIH with 4 1/2"12.6#L80 TXP liner f/ 2,091.0 12,832.0 00:00 13:15 2,091'to 12,832'MD. 12/27/2016 12/27/2016 1.75 COMPZ1 CASING OTHR P M/U liner hanger ass.and SCMT tool 12,832.0 12,832.0 13:15 15:00 as per SLB and Baker. Filed liner hanger tie back with pal mix. Page 19/38 Report Printed: 1/24/2017 • Operations Summary (with Timelog epths) 0 CD5-18 Cor► iii i 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) 12/27/2016 12/27/2016 0.50 COMPZ1 CASING RURD P Cleared floor of liner running tools and 12,832.0 12,832.0 15:00 15:30 changed out elevators for running liner on 4"DP. 12/27/2016 12/27/2016 2.00 COMPZ1 CASING RUNL P RIH with 4 1/2"liner on 4"DP f/ 12,832.0 15,150.0 15:30 17:30 12,832 to 15,150'MD. 12/27/2016 12/27/2016 5.25 COMPZ1 CASING CIRC P Rigged up head pin and circulated at4 15,150.0 15,150.0 17:30 22:45 bpm,590 psi while lowering MW f/ 9.3+to 9.2 ppg. SimOps, M/U 30 stands of 4"HWDP and racked back. 12/27/2016 12/27/2016 0.50 COMPZ1 CASING OWFF P OWFF 30 min. Well Static. 15,150.0 15,150.0 22:45 23:15 12/27/2016 12/28/2016 0.75 COMPZ1 CASING RUNL P Resume running 4 1/2"liner in 4"DP 15,150.0 16,389.0 23:15 00:00 in to OH f/15,150'to 16,398'MD. 12/28/2016 12/28/2016 6.50 COMPZ1 CASING RUNL P RIH w/4 1/2"liner in 4"DP in to OH f/ 16,389.0 26,983.0 00:00 06:30 16,398'to TD at 26,983.52'MD. Dropped 1.625"ball and took final running parameters. P/U=250,S/O= 145. 12/28/2016 12/28/2016 1.50 COMPZ1 WELLPR PACK P Broke circulation w/2 bpm,350 psi 26,983.0 14,195.0 06:30 08:00 and pumped liner setting ball to seat w/109.5 bbl. pressured up to 2100 psi and S/O to set hanger,no go. continued up to 2300 psi and set hanger. continued up to 2700 psi to function the pusher tool and held for 5 min. continued up to 3400 psi to release from hanger and held for 5 min and on up to 4200 psi. Bleed off and P/U to verify released from hanger. Top of liner at 14,118'MD. S/0= 163,P/U=240. 12/28/2016 12/28/2016 0.50 COMPZ1 WELLPR TRIP P L/D top single and B/D TD. 14,195.0 14,190.0 08:00 08:30 12/28/2016 12/28/2016 1.00 COMPZ1 WELLPR PRTS P R/U and pressure test 7 5/8"casing 14,190.0 14,190.0 08:30 09:30 and seals to 2000 psi for 10 min. Test good. R/D and B/D liner. 12/28/2016 12/28/2016 0.50 COMPZ1 WELLPR TRIP P Pull running tool and CMNT tool out of 14,190.0 13,714.0 09:30 10:00 liner assy.f/14,190'to 13,714'MD. OWFF. 12/28/2016 12/28/2016 0.50 COMPZ1 WELLPR CIRC P Pump 25 bbl, 10.7 ppg dry job. 13,714.0 13,714.0 10:00 10:30 12/28/2016 12/28/2016 3.25 COMPZ1 WELLPR QEVL P POOH on elevators while logging 13,714.0 10,957.0 10:30 13:45 cement f/13,714'to 10,957'MD. L/D the first 10 stands of HWDP and racked back the rest in the derrick. 12/28/2016 12/28/2016 0.75 COMPZ1 WELLPR TRIP P POOH f/10,957'MD to 10,008'MD. 10,957.0 10,008.0 13:45 14:30 12/28/2016 12/28/2016 1.25 COMPZ1 WELLPR SLPC P Slip and cut 98'of drill line. Serviced 10,008.0 10,008.0 14:30 15:45 TD. 12/28/2016 12/28/2016 2.00 COMPZ1 WELLPR EQRP T Changed out MWD pressure sensor 10,008.0 10,008.0 15:45 17:45 and cables on goose neck. SimOps changed out bell guide bolts. 12/28/2016 12/28/2016 5.50 COMPZ1 WELLPR TRIP P POOH f/10,008'to 96'MD. 10,008.0 96.0 17:45 23:15 Calculated fill=89.78,actual=121 bbl. 12/28/2016 12/29/2016 0.75 COMPZ1 WELLPR BHAH P L/D SCMT tool and break liner running 96.0 0.0 23:15 00:00 tool. 12/29/2016 12/29/2016 0.50 COMPZ1 WELLPR BHAH P L/D SCMT tool and liner running tool. 0.0 0.0 00:00 00:30 Page 20/38 Report Printed: 1/24/2017 ryi • Operations Summary (with Timelog Dpths) 12$14 ' , CD5-18 Conocothilllps 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 (ft)(B) End Depth(ftKB) 12/29/2016 12/29/2016 0.75 COMPZ1 WELLPR RURD P Clean and clear rig floor. Mobilize 0.0 0.0 00:30 01:15 tools to the rig floor and B/D lines. 12/29/2016 12/29/2016 5.25 PROD2 WHPST BHAH P P/U Whipstock BHA components to 0.0 253.0 01:15 06:30 the rig floor. M/U milling assy.and scribe,92 deg from MWD,place in mouse hole. M/U space out assy and whipstock slide,connect milling assy and whipstock with 35k bolt and run in hole. 12/29/2016 12/29/2016 1.75 PROD2 WHPST TRIP P RIH f/253'to 1,671'MD. 253.0 1,671.0 06:30 08:15 12/29/2016 12/29/2016 0.50 PROD2 WHPST DHEQ P Shallow test MWD w/220 gpm,540 1,671.0 1,671.0 08:15 08:45 psi. Test Good. B/D TD. 12/29/2016 12/29/2016 3.25 PROD2 WHPST TRIP P RIH f/1,671'to 5,446'MD while filling 1,671.0 5,446.0 08:45 12:00 pipe every 20 stands. 12/29/2016 12/29/2016 0.50 PROD2 WHPST SVRG P Serviced IBOP and observed a leak 5,446.0 5,446.0 12:00 12:30 dripping. 12/29/2016 12/29/2016 0.75 PROD2 WHPST TRIP P RIH f/5,446'to 6,389'MD. SimOps 5,446.0 6,389.0 12:30 13:15 prep equipment on floor to install new IBOP and saver sub. 12/29/2016 12/29/2016 4.25 PROD2 WHPST RGRP T Change out both Auto and Manual 6,389.0 6,389.0 13:15 17:30 IBOP,as well as the saver sub 12/29/2016 12/29/2016 1.25 PROD2 WHPST PRTS T Pressure test IBOPs. SimOps,P/U 6,389.0 6,389.0 17:30 18:45 RCD bearing to rig floor. 12/29/2016 12/30/2016 5.25 PROD2 WHPST TRIP P RIH F/6,389'to 12,678'MD. 6,389.0 12,678.0 18:45 00:00 12/30/2016 12/30/2016 1.50 PROD2 WHPST TRIP P RIH f/12,678'to 13,995'MD and 12,678.0 13,995.0 00:00 01:30 located RA tag at 13,852.5'MD. 12/30/2016 12/30/2016 0.75 PROD2 WHPST CIRC P Break circulation and take parameters. 13,995.0 13,995.0 01:30 02:15 220 gpm, 1100 psi,P/U=205,S/O= 161. 12/30/2016 12/30/2016 1.00 PROD2 WHPST WPST P Orient Whipstock 37 deg.LOH. RIH 13,995.0 13,998.0 02:15 03:15 and tag top of liner at 14,120.81'MD with 5k. Test seals to 1300 psi for 5 min and chart. Bleed off and S/0 14k to set anchor. Confirmed set with 10k overpull. S/O 40k and sheared mill from whipstock. Whipstock Set 37 deg.LOH TOW=13,998.58'MD BOW=14,012.17'MD 12/30/2016 12/30/2016 1.50 PROD2 WHPST DISP P Displace well from 9.2 ppg brine to 9 13,998.0 13,998.0 03:15 04:45 ppg FloPro. 300 gpm,2190 psi. 12/30/2016 12/30/2016 6.00 PROD2 WHPST MILL P Mill window f/13,998'to 14,012'MD 13,998.0 14,012.0 04:45 10:45 as per Baker. 225 gpm, 1750 psi,80- 100 rpm,3.5-5k TQ. 12/30/2016 12/30/2016 3.50 PROD2 WHPST DDRL P Drill 21'of OH f/14,012'to 14033'MD. 14,012.0 14,033.0 10:45 14:15 12/30/2016 12/30/2016 0.75 PROD2 WHPST REAM P Ream and polish the window 2 time 14,033.0 14,012.0 14:15 15:00 and drift through w/o rotation or pumps. 12/30/2016 12/30/2016 0.75 PROD2 WHPST CIRC P Circulate BU and rack pack a stand to 14,012.0 13,998.0 15:00 15:45 13,998'MD. 275 gpm,2050 psi. 12/30/2016 12/30/2016 0.50 PROD2 WHPST OWFF P OWFF,Well static. B/D TD. 13,998.0 13,998.0 15:45 16:15 Page 21/38 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) CD5-18 C®rtocoPhiiiips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/30/2016 12/30/2016 1.00 PROD2 WHPST FIT P Rigged up test equipment. Performed 13,998.0 13,998.0 16:15 17:15 FIT to 12.1 ppg EMW with 9 ppg FloPro in the hole and 1200 psi back pressure,test held. Bled off pressure, blew down lines,and rigged down test equipment. 12/30/2016 12/30/2016 0.75 PROM WHPST MPDA P Remove trip nipple and install RCD 13,998.0 13,998.0 17:15 18:00 bearing. 12/30/2016 12/30/2016 1.25 PROD2 WHPST SMPD P SOOH f/13,998'to 13,494'MD on 4" 13,998.0 13,494.0 18:00 19:15 DP with 100/450 psi in/out of slips. UD 3 joint of bad 4"DP. 12/30/2016 12/30/2016 0.50 PROD2 WHPST CIRC P Pump 39 bbl, 11.5 ppg dry job. 13,494.0 13,494.0 19:15 19:45 12/30/2016 12/30/2016 1.00 PROD2 WHPST SMPD P SOOH w/4"DP f/13,494'to 12,831' 13,494.0 12,831.0 19:45 20:45 MD holding 50/400 psi in/out of slips. 12/30/2016 12/31/2016 3.25 PROD2 WHPST SMPD P SOOH with 4"HWDP f/12,831'to 12,831.0 11,124.0 20:45 00:00 11,124'MD holding 50/400 psi in/out of slips. UD 57 joints of HWDP in pipe shed. 12/31/2016 12/31/2016 12.50 PROD2 WHPST SMPD P SOOH f/11,124'to 790'MD holding 11,124.0 790.0 00:00 12:30 50/400 psi in/out of slips.UD worn DP joints. 12/31/2016 12/31/2016 0.50 PROD2 WHPST OWFF P OWFF,well static. Clean and clear rig 790.0 790.0 12:30 13:00 floor. B/D TD. 12/31/2016 12/31/2016 0.75 PROD2 WHPST MPDA P Pull RCD bearing and install trip 790.0 790.0 13:00 13:45 nipple. 12/31/2016 12/31/2016 1.25 PROD2 WHPST TRIP P POOH on trip tank f/790'to 131'MD. 790.0 131.0 13:45 15:00 12/31/2016 12/31/2016 1.50 PROD2 WHPST BHAH P L/D milling assy as per Baker. Upper 131.0 0.0 15:00 16:30 watermelon mill was in gage. 12/31/2016 12/31/2016 0.50 PROD2 WHPST BHAH P Clean and clear rig floor. 0.0 0.0 16:30 17:00 12/31/2016 12/31/2016 1.00 PROD2 WHDBOP RURD P Flush stack and pull wear ring as per 0.0 0.0 17:00 18:00 FMC. P/U 4 1/2"test joint and plug and set in well head. 12/31/2016 1/1/2017 6.00 PROD2 WHDBOP BOPE P R/U and test BOPE with 4 1/2"test 0.0 0.0 18:00 00:00 joint 250/3500 psi.AOGCC Jeff Jones wittnessed.Tested annular to 250/2500 psi.Tested 3W"x 6""upper and lower VBR's w/both test joints, blind rams,choke valves#1-14, needle valve above#1,4""kill line Demco,4""XT39 Dart,4"XT39 FOSV,HCR and manual choke and kill valves to 250/3500 psi for 5 minutes each.Performed accumulator test.System pressure=3000 psi, Pressure after functioning rams and annular=1500 psi,200 psi attained=28.5 sec,Full system recovery=158 sec,4 bottle N2 average=2100 psi. Tested gas alarms and PVT alarm systems. 1/1/2017 1/1/2017 2.75 PROD2 WHDBOP BOPE P Finished Testing BOPE with 3 1/2" 0.0 0.0 00:00 02:45 test joint. Tested Annular 250/2500 psi,Upper,lower,and blind rams to 250/3500 psi. Test witnessed by AOGCC Jeff Jones. Page 22/38 Report Printed: 1/24/2017 !erations Summary (with Timelog PPths) F CD5-18 ConocaPhitlips n. 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) 1/1/2017 1/1/2017 1.00 PROD2 WHDBOP RURD P R/D test equipment,B/D lines and 0.0 0.0 02:45 03:45 drain stack. Set 7.125"wear ring as per FMC and mobilize BHA equipment to the rig floor. 1/1/2017 1/1/2017 1.50 PROD2 WHPST BHAH P M/U 6 3/4"BHA as per SLB. 0.0 124.0 03:45 05:15 1/1/2017 1/1/2017 2.00 PROD2 WHPST PULD P Single in hole f/124'to 1,718'MD with 124.0 1,718.0 05:15 07:15 4"14#DP from pipe shed. 1/1/2017 1/1/2017 0.75 PROD2 WHPST DHEQ T Attempt to shallow test MWD with both 1,718.0 1,718.0 07:15 08:00 pumps at 220-250 gpm,990-1290 psi. Could not communicate with tools below MWD. Decision made to POOH and run backup tools. 1/1/2017 1/1/2017 0.25 PROD2 WHPST OWFF T OWFF,Well static. 1,718.0 1,718.0 08:00 08:15 1/1/2017 1/1/2017 2.25 PROD2 WHPST TRIP T POOH f/1,718'to 124'MD 1,718.0 124.0 08:15 10:30 1/1/2017 1/1/2017 1.25 PROD2 WHPST BHAH T Flush BHA and attempted to establish 124.0 0.0 10:30 11:45 communication at surface with no success. L/D MWD tools to the pipe shed. 1/1/2017 1/1/2017 1.50 PROD2 WHPST BHAH T Change out MWD components in the 0.0 0.0 11:45 13:15 pipe shed as per SLB. SimOps M/U and rack back 2 stands of 4"DP. 1/1/2017 1/1/2017 0.75 PROD2 WHPST BHAH T M/U new 6 3/4"BHA. 0.0 303.0 13:15 14:00 1/1/2017 1/1/2017 1.25 PROD2 WHPST PULD T RIH on singles f/303'to 1,533'MD. 303.0 1,533.0 14:00 15:15 1/1/2017 1/1/2017 0.75 PROD2 WHPST DHEQ P Shallow test MWD with 220-240 gpm, 1,533.0 1,533.0 15:15 16:00 1000-1270 psi,40 rpm, 1k TQ. Test Good. 1/1/2017 1/2/2017 8.00 PROD2 WHPST TRIP P RIH f/1,533'to 12,917'MD while filling 1,533.0 12,917.0 16:00 00:00 pipe every 20 stands. 1/2/2017 1/2/2017 1.75 PROD2 WHPST TRIP P RIH f/12,917'to 13,817'MD,culling 5 12,917.0 13,817.0 00:00 01:45 worn joints on the way in. 1/2/2017 1/2/2017 0.50 PROD2 WHPST DLOG P Wash down and log past the RA tag at 13,817.0 13,907.0 01:45 02:15 13,852'. Identified tag at 13,846'MD. 230 gpm,2030 psi,P/U=187,S/O= 140. 1/2/2017 1/2/2017 1.25 PROD2 WHPST SLPC P Slip&Cut 53'of dril line. 13,907.0 13,907.0 02:15 03:30 1/2/2017 1/2/2017 0.50 PROD2 WHPST SVRG P Service rig,T/D.D/W,and installed 13,907.0 13,907.0 03:30 04:00 new light in crown. 1/2/2017 1/2/2017 0.50 PROD2 WHPST MPDA P Pulled trip nipple and installed RCD 13,907.0 13,907.0 04:00 04:30 bearing. 1/2/2017 1/2/2017 0.50 PROD2 WHPST WASH P Wash down through whipstock f/ 13,907.0 14,027.0 04:30 05:00 13,907'to 14,027'MD. 1/2/2017 1/2/2017 0.50 PROD2 DRILL REAM P Send initial downlink to tools and 14,027.0 14,033.0 05:00 05:30 clean out rat hole f/14,027'to 14,033' MD. 275 gpm,2560 psi,60 rpm,4-7k TQ. 1/2/2017 1/2/2017 15.00 PROD2 DRILL DDRL P Drill f/14,033 to 15,145'MD while 14,033.0 15,145.0 05:30 20:30 displacing to 8.6 ppg VersaPro on the fly. 276 gpm,2940 psi, 140 rpm, 15k TQ, 12/15k WOB,9.6 ppg ECD. 1/2/2017 1/2/2017 0.25 PROD2 DRILL CIRC P Circulated for 15 min to clear cuttings 15,145.0 15,145.0 20:30 20:45 from BHA and OH. 280 gpm,3080 psi, 140 rpm, 15k TQ. Page 23/38 Report Printed: 1/24/2017 Operations Summary (with Timelo Depths) c s_ CD5-18 Conocc"iiiips til smka 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) 1/2/2017 1/2/2017 0.25 PROD2 DRILL OWFF P OWFF,Well Static.Possible slight 15,145.0 15,145.0 20:45 21:00 loss. 1/2/2017 1/2/2017 0.75 PROD2 DRILL MPDA P Removed RCD bearing and installed 15,145.0 15,145.0 21:00 21:45 trip nipple. 1/2/2017 1/3/2017 2.25 PROD2 DRILL DDRL P Drill ahead f/15,145'to 15,432'MD, 15,145.0 15,432.0 21:45 00:00 7,526'TVD. 280 gpm,3220 psi, 140 rpm, 13 TQ, 14k WOB,9.77 ppg ECD, P/U=235,S/O=115. 1/3/2017 1/3/2017 12.00 PROD2 DRILL DDRL P Directional drill ahead f/15,432'to 15,432.0 16,671.0 00:00 12:00 16,671'MD,7,562'TVD.ADT=8.32 hrs,P/U=230k,S/0=120k, ROT=165k, 140 rpm,Tq on/off=12.5k/10k,280 gpm,3350 psi,ECD=9.78. OA pressure @ 11:30 hrs=600 psi 1/3/2017 1/4/2017 12.00 PROD2 DRILL DDRL P Directional drill ahead f/16,671'to 16,671.0 17,750.0 12:00 00:00 17,750'MD,7,565'TVD.ADT=8.27 hrs, P/U=239k,5/0=112k,ROT=161k, 140 rpm,Tq on/off=14.5k/11.5k,280 gpm,3500 psi,ECD=9.56. Crossed fault @ 16,880',25'DTS, back in C @ 17,120'MD. Fluid static- slight drop on connections. Recorded mud loss for 24 hr=7 bbl. OA pressure @ 23:00 hrs=600 psi 1/4/2017 1/4/2017 11.75 PROD2 DRILL DDRL P Directional drill ahead f/17,750'to 17,750.0 19,051.0 00:00 11:45 19,051'MD,7,576'TVD.ADT=7.78 hrs,P/U=255k,5/0=118k,ROT=162k, 140 rpm,Tq on/off=17k/14.5k,280 gpm,3650 psi, ECD=9.91. OA pressure @ 11:00 hrs=575 psi 1/4/2017 1/4/2017 0.50 PROD2 DRILL SVRG P Service rig,change out wash pipe on 19,051.0 19,051.0 11:45 12:15 top drive.Circulate @ 3 bpm, 1130 psi. 1/4/2017 1/5/2017 11.75 PROD2 DRILL DDRL P Directional drill ahead f/19,051'to 19,051.0 19,907.0 12:15 00:00 19,907'MD,7,581'TVD.ADT=8.51 hrs, P/U=224k,S/0=102k,ROT=162k, 140-180 rpm,Tq on/off=13.5k/11 k, 280 gpm,3750 psi,ECD=9.92. Varying rpm from 140-180 rpm for directional control due LH tendancy. Slow MWD data rate to 1 hz/1 bps for surveys. OA pressure @ 23:00 hrs=550 psi 1/5/2017 1/5/2017 5.75 PROD2 DRILL DDRL P Directional drill ahead f/19,907'to 19,907.0 20,316.0 00:00 05:45 20,316'MD,7,592'TVD.ADT=4.61 hrs,P/U=230k,S/0=115k,ROT=162k, 140-180 rpm,Tq on/off=14.5k/10k, 280 gpm,3800 psi,ECD=9.94. Page 24/38 Report Printed: 1/24/2017 •erations Summary (with TimelogDepths) Cot CD5-18 Conocol'ttillips 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) 1/5/2017 1/5/2017 6.25 PROD2 DRILL WAIT T Phase Ill Weather conditions-Rack 20,316.0 20,287.0 05:45 12:00 back stand to 20,287'.CBU x 2 @ 280 gpm,3740 psi, 140-180 rpm, 12-10.5k Tq.SLB switch modes to find optimum range for drilling ahead,260 gpm 3150 psi,30 rpm, 10k Tq.Obtain SPR's. OA pressure @ 12:00 hrs=250 psi 1/5/2017 1/5/2017 6.75 PROD2 DRILL WAIT T Phase III Weather conditions- 20,287.0 20,287.0 12:00 18:45 Continue to circulate 260 gpm, continue testing MWD modes/data rates. Reduce to 80 gpm,710 psi and wait on weather. 1/5/2017 1/6/2017 5.25 PROD2 DRILL DDRL P Return to Phase II,roads open. 20,287.0 20,668.0 18:45 00:00 Resume directional drilling ahead f/ 20,316'to 20,668'MD,7,597'TVD. ADT=3.52 hrs, P/U=228k,S/0=108k, ROT=163k, 140-180 rpm,Tq on/off=14k/11k,280 gpm,3840 psi, ECD=9.97. OA pressure @ 23:00 hrs=450 psi 1/6/2017 1/6/2017 12.00 PROD2 DRILL DDRL P Directional drill ahead f/20,668'to 20,668.0 21,623.0 00:00 12:00 21,623'MD,7,615'TVD.ADT=8.88 hrs,P/U=240k,S/0=---k,ROT=165k, 140 rpm,Tq on/off=14.5k/11.5,280 gpm,3900 psi,ECD= 10.12.Lost Slack off weight at 21,336'MD. Double checking all Super Slider torque via 90'mousehole prior to P/U and RIH. OA pressure @12:00 hrs=500 psi 1/6/2017 1/7/2017 12.00 PROD2 DRILL DDRL P Directional drill ahead f/21,623'to 21,623.0 22,378.0 12:00 00:00 22,378'MD,7,624'TVD.ADT=9.89 hrs, P/U=230k,S/0=---k, ROT=162k, 140 rpm,Tq on/off=12.8k/11.6,280 gpm,4000 psi,ECD=10.02. Double checking all Super Slider torque via 90'mousehole prior to P/U and RIH. OA pressure @ 23:00 hrs=540 psi 1/7/2017 1/7/2017 12.00 PROD2 DRILL DDRL P Directional drill ahead f/22,378'to 22,378.0 23,052.0 00:00 12:00 23,052'MD,7,636'TVD.ADT=9.33 hrs,P/U=270k,S/0=---k,ROT=162k, 140 rpm,Tq on/off=14k/12.5,280-275 gpm,4050 psi,ECD= 10.23. Double checking all Super Slider torque via 90'mousehole prior to P/U and RIH. OA pressure @ 11:00 hrs=600 psi Page 25/38 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) fi CD5-18 ConocoPtiiiilps 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) 1/7/2017 1/7/2017 6.00 PROD2 DRILL DDRL P Directional drill ahead f/23,052'to 23,052.0 23,331.0 12:00 18:00 23,331'MD,7,634'TVD.ADT=5.63 hrs,P/U=270k,S/0=---k,ROT=163k, 140 rpm,Tq on/off=15.2k/13.5k,275 gpm,4000 psi,ECD=10.25. Double checking all Super Slider torque via 90'mousehole prior to P/U and RIH. Observe packoff while drilling @ 23,331'MD. 1/7/2017 1/7/2017 1.00 PROD2 DRILL CIRC T Attempt to re-gain full circulation rate, 23,331.0 22,230.0 18:00 19:00 achieve 1.5-2.5 bpm and observe multiple packoffs while increaseing rate/pulling stand.Rack back stand. Confer with engineer and decide to BROOH @ 20 rpm, 1.5-2 bpm until) past B sump @ 22.610'-22,310'MD. 1/7/2017 1/8/2017 5.00 PROD2 DRILL BKRM T Backream out of hole from 22,230'MD 22,230.0 22,765.0 19:00 00:00 to 22,719'MD @ 1.5-2 bpm,770-880 psi,23 rpm, 15k Tq.Observe several minor packoffs on first stand,then able to pull 400 fph @ 2 bpm to 22,719'MD.Not able to work past. Torqueing up and stalling out, packoffs @<1 bpm.Attempt to creep out,holding 200-400 psi but again torque up and stall out.Drop to 22,765'and attempt to regain circulation. 1/8/2017 1/8/2017 1.75 PROD2 DRILL CIRC T Attempt to regain full circulation @ 22,765.0 22,765.0 00:00 01:45 22,765'MD, .5 bpm-1.7 bpm,470-790 psi, 12.5-18.5k Tq.Multiple packoffs when moving pipe. 1/8/2017 1/8/2017 2.25 PROD2 DRILL REAM T Ream down 22,765'to 22,861'MD,20 22,765.0 22,861.0 01:45 04:00 -60 rpm, 12.5-18.5k to regain circulation,.5-1.5 bpm,470-750 psi, stage pumps.5 bpm to 2.5 bpm,470- 1120 psi,packoff multiple times while moving pipe. 1/8/2017 1/8/2017 0.25 PROD2 DRILL REAM T Ream down from 22,861'MD to 22,861.0 22,881.0 04:00 04:15 22,881'MD 60 rpm,.5-1 bpm,450- 610 psi. 1/8/2017 1/8/2017 1.25 PROD2 'DRILL CIRC T Park the pipe @ 22,881'MD to gain 22,881.0 22,881.0 04:15 05:30 circulation.Stage up from.5 bpm to 1.8 bpm,450-990 psi,60 rpm, 11.5- 17.5k,full returns. 1/8/2017 1/8/2017 6.50 PROD2 DRILL CIRC T Reciprocate pipe from 22,860'MD to 22,881.0 22,907.0 05:30 12:00 22,907'MD pack off.Stage pumps up from.5 bpm to 1.8 bpm 440-990 psi, 25 rpm, 16.5-11.5k.Stage pumps up on the upstroke in 1/4 bbl steps,S/O and P/U 2'each stroke to gain working length of string.Pack off @ 1.8 bpm, could not increase flow rate.Decision made to weight up to 8.9 ppg. OA pressure=20 psi Page 26/38 Report Printed: 1/24/2017 • Operations Summary (with Timelog Depths) tj CD5-18 CornocoPhitiips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) ..Phase Op Code Activity Code Time P-T-X Operation'. (ftK8) End Depth(ftK8) 1/8/2017 1/9/2017 12.00 PROD2 CASING CIRC T Begin weight up to 8.9 ppg, 22,907.0 22,800.0 12:00 00:00 reciprocate between 22,905'MD and 22,865'experiencing packoffs above 1.5 bpm.park pipe at 22,875'MD and stage up to 1.8 bpm.At 4200 stks started seeing erratic torque,9-12k then increase to 14k with associated packoffs,pressure.Move pipe down to 22,915'to move tool joints and regain circ without success. Pulled up,rack back stand to 22,859'and establish circ again,stage up to 1.5 bpm then see torque and packoff @ 6300 stks. Pull another joint across to 22,835' regain circ,stage up to 1.2 bpm,Tq and PO again @ 6800 stk.Pull another joint to 22,800'and repeat, stage up to 1.1 bpm 1/9/2017 1/9/2017 2.00 PROD2 CASING CIRC T Continue weighting up from 8.6 ppg to 22,800.0 22,765.0 00:00 02:00 8.9 ppg,.5 bpm to 1.1 bpm,observing packoff and torque around 1 bpm, Continue pulling one joint after each packoff to regain circulation.Pull to 22,765'MD circulate until torrque increased from 12k to 15k and pressure increased from 650 psi to 770 psi @ 1 bpm.Rack back stand. 1/9/2017 1/9/2017 1.75 PROD2 CASING CIRC T Regain circulation @.5 bpm 410 psi, 22,765.0 22,760.0 02:00 03:45 20 rpm 12k Tq.Continue weighting up from 8.6 ppg to 8.9 ppg,.5 bpm to 1.2 bpm 770 psi until observing packoff beginning.MW 8.9 ppg in,8.8 ppg out. 1/9/2017 1/9/2017 8.25 PROD2 CASING BKRM T Backream out of hole from 22,670'MD 22,760.0 22,307.0 03:45 12:00 to 22,307'MD,20 rpm holding 80-120 psi pressure on drill string to offset swab.Begin pulling @ 100-150 fpm, (clean hole)torque 12-14k,ROT- P/U=180-185k.Backream out adjusting pulling speed to<50 fph as required to maintain torque below 15k desired,20k max,<10k overpull. (Rig off highline power @ 07:00 for production emission testing)Running Cat 1,3&4. OA pressure @ 12:00 hrs=10 psi 1/9/2017 1/9/2017 4.25 PROD2 CASING BKRM T Continue backreaming out from 22,307.0 22,254.0 12:00 16:15 22,307'MD to 22,254'MD as above, observing torque climb to 20k,reduce pulling speed as required to<20 fpm and work through exit of B sump, observe torque drop to 12k and pump pressure drop @ 22,254'MD. Rig off Gen power @ 14:15 hrs,back on highline. Page 27/38 Report Printed: 1/24/2017 • AS Operations Summary (with Timelog Depths) 444,43t2 ' CD5-18 ConocoPhiltips 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) 1/9/2017 1/9/2017 6.50 PROD2 CASING CIRC P Stage pumps up to 6.5 bpm/274 gpm, 22,254.0 22,003.0 16:15 22:45 rotary 140 rpm, 10.2-11.3k Tq. Circulate 3 bottoms up,racking back stand each bottom up to 22,203'MD. OA presssure©21:00 hrs=250 psi 1/9/2017 1/10/2017 1.25 PROD2 CASING CIRC P Pump 35 bbl Low Vis 8.9 ppg followed 22,003.0 22,003.0 22:45 00:00 by 35 bbl Hi Vis 8.9 ppg sweeps @ 270 gpm,4060 psi, 140-180 rpm, 10.5 -12k Tq.Reciprocate stand while circulating sweep around. P/U=230k,S/O=N/A, ROT=163k. 1/10/2017 1/10/2017 2.00 PROD2 CASING CIRC P Continue circulating around 35 bbl 22,003.0 22,003.0 00:00 02:00 Low Vis 8.9 ppg followed by 35 bbl Hi Vis 8.9 ppg sweeps @ 270 gpm,4060 psi ICP,3950 FCP, 140-180 rpm, 10.5 -12k Tq. Reciprocate stand while circulating sweep around.Regained SOW that was lost @ 21,336'while drilling.Total pumped 5 X bottoms up. P/U=225k,S/0=105k, ROT=165k. 1/10/2017 1/10/2017 0.50 PROD2 CASING OWFF P Observe well for flow while rotating 22,003.0 22,003.0 02:00 02:30 string 5 rpm,9-10.5k Tq.Slow exhale for 10 minutes then static slight drop. 1/10/2017 1/10/2017 3.00 PROD2 CASING PMPO P Pump out of hole from 22,003'MD to 22,003.0 20,668.0 02:30 05:30 20,668'MD @ 200 gpm,2320 psi, start 500 fpm stage up to 1200 fpm pulling speed.Observe no overpull or pressure indicators.Pumping P/U=235k-220k. 1/10/2017 1/10/2017 0.50 PROD2 CASING CIRC P Circulate 200 bbl open hole volume 20,668.0 20,668.0 05:30 06:00 per program prior to installing MPD element @ 270 gpm,3800 psi, 140 rpm, 11k Tq. PJSM on pulling trip nipple and installing MPD. 1/10/2017 1/10/2017 0.25 PROD2 CASING OWFF P Observe well for flow,slow exhale for 20,668.0 20,668.0 06:00 06:15 10 minutes then static slight drop. 1/10/2017 1/10/2017 0.50 PROD2 CASING MPDA P Blow down top drive,pull trip nipple 20,668.0 20,668.0 06:15 06:45 and install MPD bearing/element. 1/10/2017 1/10/2017 1.50 PROD2 CASING SMPD P Strip out with MPD @ 2000 fph from 20,668.0 19,240.0 06:45 08:15 20,668'MD to 19,240'MD per schedule holding 180 psi pulling,30 psi in slips. 1/10/2017 1/10/2017 1.50 PROD2 CASING BKRM P Backream out from 19,240'MD to 19,240.0 18,955.0 08:15 09:45 18,955'MD per plan to smooth out dogleg @—19,084'.SIMOPS-re-shoot surveys(pumped up while backreaming)at 19,143'and 19,050' MD bit depths to confirm DLS. Corrected surveys reduced DLS from 12.66°to 2.6°. 1/10/2017 1/10/2017 1.75 PROD2 CASING SMPD P Continue stripping out with MPD @ 18,955.0 17,147.0 09:45 11:30 2000 fph from 18,955'MD to 17,147' MD per schedule holding 180 psi pulling,30 psi in slips. OA pressure @ 11:00 hrs=0 psi Page 28/38 Report Printed: 1/24/2017 % it 0 s' j Operations Summary -(with18 Timelog iPpths) .,liti,!,,,, ConocoPhit ipTa 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) 1/10/2017 1/10/2017 3.00 PROD2 CASING BKRM P Backream out from 17,147'MD to 17,147.0 16,093.0 11:30 14:30 16,093'MD per plan through fault#1 & B sump @ 270 gpm 3400 psi, 120 rpm,9-10k Tq. P/U=212k,S/0=130k,ROT=160k @ 16,956'MD 1/10/2017 1/10/2017 3.25 PROD2 CASING PMPO P Pump out of hole per plan from 16,093.0 14,850.0 14:30 17:45 16,093'MD to 14,850'MD(Horizontal C)@ 270 gpm,3400 psi. SIMOPS-Re-shoot survey @ 15,621' MD bit depth due flagged status. 1/10/2017 1/10/2017 1.50 PROD2 CASING BKRM P Backream out from 14,850'MD to 14,850.0 14,300.0 17:45 19:15 14,300'MD per plan through window exit sump @ 270 gpm 3200 psi, 120 rpm,9-10k Tq. 1/10/2017 1/10/2017 1.75 PROD2 CASING PMPO P Pump out of hole per plan from 14,300.0 13,908.0 19:15 21:00 14,300'MD to 13,908'MD(Window) @ 270 gpm,3220 psi and no rotary. Pull Orbit and bit through window without pump.Observe no more than 10k intermittant drag as stabilizers and bit enter window. 1/10/2017 1/10/2017 1.75 PROD2 CASING CIRC P CBU x 1.5,reciprocate from 13,908' 13,908.0 13,908.0 21:00 22:45 MD to 13,814'MD @ 275 gpm 120 rpm 8k Tq.SIMOPS-Log RA tag with Periscope and Impulse. Pull up to 13,877'MD and log down @ 50 fph due low data rate to loag RA tag with Perriscope(Impulse not on). Periscope P/U PIP @ 13,844'MD,8' shallow.Sent downlink to wake Impulse,and downlink to increase data rate.P/U to 13,815',slack off to 13,850'bit depth and log down @ 200 fph.Confirmed both Periscope and Impulse identified PIP tag @ 13,844' MD,370-404 gAPI. 1/10/2017 1/10/2017 0.50 PROD2 CASING OWFF P Line up MPD and flow check well 13,908.0 13,908.0 22:45 23:15 static 30 min. SIMOPS clean rig floor,prep for SOOH. OA pressure @ 23:00 hrs=0 psi 1/10/2017 1/10/2017 0.25 PROD2 CASING CIRC P Pump and chase to pipe 32 bbl 11.4 13,908.0 13,908.0 23:15 23:30 ppg dry job @ 270 gpm, 120 rpm 8k Tq. 1/10/2017 1/10/2017 0.25 PROD2 CASING MPDA P Line up pump#1 for SOOH,establish 13,908.0 13,908.0 23:30 23:45 circulation via RCD and choke manifold.Blow down top drive,drop 2.10"hollow drift with 110'wire tail. 1/10/2017 1/11/2017 0.25 PROD2 CASING SMPD P Strip out with MPD @ 4000 fph from 13,908.0 13,483.0 23:45 00:00 13,908'MD to 13,483'MD per schedule holding 180 psi pulling,30 psi in slips. P/U=210k,S/0=125k,ROT=155k @ 13,908'MD Daily mud losses=92 bbl,Cumulative interval=444 bbl Page 29/38 Report Printed: 1/24/2017 °a • EA •erations Summary (with Timelog•pths) 1 0 CD5-18 C> 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 (ftKB) End Depth(ftKB) 1/11/2017 1/11/2017 8.50 PROD2 CASING SMPD P Continue stripping out with MPD @ 13,483.0 1,246.0 00:00 08:30 4000-6000 fph from 13,483'MD to 1,246'MD per schedule holding 180/80 psi pulling,30 psi in slips. Monitor hole fill-good displacemenmt. Pushing away<1 bph with MPD.Pipe pulling dry. SLM as pipe racked back. Inspecting for worn hardbanding,observe some wear from stand 75-60,start marking reject pipe from stand 60.85-90%of lower 5,000'will need re-banding. 1/11/2017 1/11/2017 0.50 PROD2 CASING OWFF P Line up MPD and monitor well for flow, 1,246.0 1,246.0 08:30 09:00 static. SIMOPS-PJSM on pulling MPD element. 1/11/2017 1/11/2017 0.50 PROD2 CASING MPDA P Blow down MPD equipment.Pull and 1,246.0 1,246.0 09:00 09:30 strip off element,install trip nipple. 1/11/2017 1/11/2017 1.00 PROD2 CASING TRIP P POOH on trip tank from 1,246'MD to 1,246.0 303.0 09:30 10:30 303'MD,retrieve 2.11"drift from top of jars.OWFF @ HWDP-Static SIMOPS-PJSM for laying down BHA. 1/11/2017 1/11/2017 1.50 PROD2 CASING BHAH P L/D BHA#6 per DD/MWD from 303' 303.0 0.0 10:30 12:00 MD to surface,observe wear on stabilizers and bit ring out,inner and outer tooth wear/loss. OA pressure @ 12:00 hrs=0 psi 1/11/2017 1/11/2017 0.50 COMPZ2 CASING BHAH P Clean and clear rig floor of BHA tools 0.0 0.0 12:00 12:30 and handling equipment. 1/11/2017 1/11/2017 1.50 COMPZ2 CASING RURD P P/U and rig up 4%2' liner tools and 0.0 0.0 12:30 14:00 equipment,power tongs,elevators, slips. 1/11/2017 1/11/2017 5.00 COMPZ2 CASING PUTB P P/U 4W 12.6#L-80 TXP liner per 0.0 3,286.0 14:00 19:00 detail,Orange peel shoe,7 perf pups, 83 joints liner with 4W x 6W Hydroforms,XO and HRDE liner setting sleeve.Torque TXP connections to 7,000 ft/lbs. 1/11/2017 1/11/2017 0.50 COMPZ2 CASING CIRC P Run in one stand to 3,373'MD, 3,286.0 3,373.0 19:00 19:30 establish circulation through liner @ 2 bpm, 120 psi.Blow down top drive, install wiper and air slips. 1/11/2017 1/12/2017 4.50 COMPZ2 CASING RUNL P Run liner on 4"14#XT-39 drill pipe 3,373.0 8,863.0 19:30 00:00 from 3,373'MD to 8,863'MD @ 2000- 3000 fph.Pipe self filling,good pipe displacement.Check P/U weight every 20 stands.P/U=147k,S/0=115k @ 8,863'MD OA pressure @ 23:00 hrs=0 psi Daily mud losses=22 bbl,Cumulative interval=466 bbl 1/12/2017 1/12/2017 3.75 PROD2 CASING RUNL P Continue run liner on 4"14#XT-39 8,863.0 13,959.0 00:00 03:45 drill pipe from 8,863'MD to 13,959' MD @ 2000-3000 fph.Pipe self filling, good pipe displacement.Check P/U- S/0 weight every 20 stands. Page 30/38 Report Printed: 1/24/2017 •erations Summary (with TimelogDepths) 1 re CD5-18 C:onocot+hithps 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) 1/12/2017 1/12/2017 2.00 PROD2 CASING CIRC P Circulate bottoms up per plan 431 bbl, 13,959.0 13,959.0 03:45 05:45 1-4.5 bpm,390-1040 psi.Obtain parameters before window exit. P/U=195k,S/0=132k, ROT=160k. 10/20 rpm=7k Tq.Blow down top drive. 1/12/2017 1/12/2017 3.50 COMPZ2 CASING RUNL P Run liner on 4"DP into C lateral from 13,959.0 17,314.0 05:45 09:15 13,959'MD to 17,313.95'MD shoe depth.P/U=215k,S/0=125k.Calc Disp=89 bbl,Actual Disp=82 bbl. 1/12/2017 1/12/2017 0.25 COMPZ2 CASING CIRC P Pump 50 bbl Hi Vis spacer,8.9 ppg @ 17,314.0 17,314.0 09:15 09:30 3-3.5 bpm,820-940 psi. 1/12/2017 1/12/2017 1.75 COMPZ2 CASING HOSO P Drop.90625"OD phenolic ball and 17,314.0 14,034.0 09:30 11:15 pump down @ 3 bpm for 90 bbl,slow rate to 1.1 bpm 390 psi.Ball on seat @ 143.2 bbl pumped.Pressure up to 2560 psi.Slack off 125k,bleed off pressure and P/U 10'@ 203k S/O @ 140 and tag TOL with 5k.P/U 22', pressure up to 4100 psi to blow out ball seat.TOL=14,034.71'MD,Liner shoe=17,313.95'MD. 1/12/2017 1/12/2017 0.25 COMPZ2 WELLPR TRIP P POOH from 14,057'MD(end of 14,034.0 13,914.0 11:15 11:30 running tools)to 13,914'MD. P/U=202k,S/0=139k pumps off. 1/12/2017 1/12/2017 3.75 COMPZ2 WELLPR CIRC P Establish circulation and weight up 13,914.0 13,914.0 11:30 15:15 mud system from 8.9 ppg to 9.2 ppg, 8.2 bpm 2720 psi,CBU x 2 with 8.9 PPg. 1/12/2017 1/12/2017 0.50 COMPZ2 WELLPR OWFF P Flow check well 15 minutes static, 13,914.0 13,914.0 15:15 15:45 blow down top drive and monitor across hole for 15 min,static.. 1/12/2017 1/12/2017 1.00 COMPZ2 WELLPR SLPC P Cut and slip 68'of drilling line. 13,914.0 13,914.0 15:45 16:45 1/12/2017 1/12/2017 0.50 COMPZ2 WELLPR SVRG P Service top drive,draw works,iron 13,914.0 13,914.0 16:45 17:15 roughneck. 1/12/2017 1/12/2017 0.25 COMPZ2 WELLPR CIRC P Break circulation and pump 20 bbl dry 13,914.0 13,914.0 17:15 17:30 job 11.4 ppg. 1/12/2017 1/13/2017 6.50 COMPZ2 WELLPR TRIP P POOH on elevators from 13,914'MD 13,914.0 8,530.0 17:30 00:00 to 8,530'MD following tripping schedule. 1000 fph initial-2000 fph. Monitor hole fill,good @ 2.5-3 bbl/5 stands. P/U=150k,S/0=117k @ 8,427'MD. OA pressure @ 23:00 hrs=0 psi Daily mud losses=35 bbl,Cumulative interval=501 bbl 1/13/2017 1/13/2017 4.75 COMPZ2 WELLPR TRIP P Continue POOH on elevators from 8,530.0 25.0 00:00 04:45 8,530'MD to liner running tools following tripping schedule. Calc Fill- 73.5 bbl,Actual Fill=85 bbl. OA pressure @ 23:00 hrs=0 psi Daily mud losses=35 bbl,Cumulative interval=501 bbl 1/13/2017 1/13/2017 0.25 COMPZ2 WELLPR OWFF P Observe well for flow,-Static 25.0 25.0 04:45 05:00 1/13/2017 1/13/2017 0.50 COMPZ2 WELLPR BHAH P Lay down Baker liner running tools. 25.0 0.0 05:00 05:30 1/13/2017 1/13/2017 0.50 COMPZ2 WHDBOP RURD P Drain stack,R/U puller and pull FMC 0.0 0.0 05:30 06:00 wear ring. Page 31/38 Report Printed: 1/24/2017 •erations Summary (with Timelog Depths) u»q' CD5-18 ConocsoPhithps 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 MKS) 1/13/2017 1/13/2017 1.00 COMPZ2 WHDBOP RURD P Set 4"test joint.Fill stack,choke and 0.0 0.0 06:00 07:00 kill lines and choke manifold with water.Purge air from system. 1/13/2017 1/13/2017 4.75 COMPZ2 WHDBOP BOPE P Test BOPE with 4"Test joint to 0.0 0.0 07:00 11:45 250/3500 psi 5 min ea charted. AOGCC Matt Herrerra waived witness.Annular tested to 250/2500 psi.Tested choke valves#1-14, needle valve above#1,Auto and manual IBOP,4"XT-39 FOSV and Dart valve,4"Demco on kill line, Manual choke and kill and HCR choke and kill on stack.Upper and lower 3'W x 6"VBR's. 1/13/2017 1/13/2017 0.25 COMPZ2 'WHDBOP BOPE P Accumulator test Full system 0.0 0.0 11:45 12:00 pressure=3000 psi,Manifold pressure=1500 psi,Annular=1200 psi. System pressure after functioning=1550 psi,200 psi attained=26 sec,Full systrem recovery=134 sec.4 bottle N2 average=2000 psi. Tested gas alarms. 1/13/2017 1/13/2017 2.00 COMPZ2 WHDBOP BOPE P Tested blind rams 250/3500 psi,test 0.0 0.0 12:00 14:00 manual and super auto choke to 1100 psi. Install 3'W test joint and test annular 250/2500 psi,upper and lower rams to 250/3500 psi 5 min each charted. 1/13/2017 1/13/2017 0.50 COMPZ2 WHDBOP RURD P Pull test plug and install wear ring per 0.0 0.0 14:00 14:30 FMC. ID=9",OD=10.875", length=1.79".Blow down choke and kill lines. 1/13/2017 1/13/2017 1.25 COMPZ2 FISH BHAH P PJSM and M/U Baker Fixed Lug 0.0 91.0 14:30 15:45 Retieval Tool and MWD per DD/MWD and Baker rep to 91'MD.Verify tool offset 86.4°. 1/13/2017 1/13/2017 1.00 COMPZ2 FISH TRIP P RIH on 4"14#DP from 91'MD to 91.0 1,981.0 15:45 16:45 1,981'MD. 1/13/2017 1/13/2017 0.25 COMPZ2 FISH DHEQ P Shallow test MWD tool @ 220 gpm, 1,981.0 1,981.0 16:45 17:00 900 psi,-good. 1/13/2017 1/13/2017 6.25 COMPZ2 FISH TRIP P RIH on 4"14#DP from 1,981'MD to 1,981.0 13,795.0 17:00 23:15 13,795'MD,filling pipe every 20 stands. P/U=200k,S/0=130k. 1/13/2017 1/13/2017 0.25 COMPZ2 FISH OWFF P Pull bushings and flow check well for 13,795.0 13,795.0 23:15 23:30 10 min,static. PJSM-Removing tip nipple and installing MPD element. 1/13/2017 1/13/2017 0.25 COMPZ2 FISH MPDA P Remove trip nipple and install RCD. 13,795.0 13,795.0 23:30 23:45 1/13/2017 1/14/2017 0.25 COMPZ2 FISH PULD P Pick up a 14.6'pup and a 30.64'single 13,795.0 13,840.0 23:45 00:00 from pipe shed, 13,795'MD to 13,840' MD.Space out BHA for logging RA tag and whipstock retrieval. OA pressure @ 23:00 hrs=20 psi Daily mud losses=21 bbl,Cumulative interval=522 bbl Page 32/38 Report Printed: 1/24/2017 4110 � �- perations Summary (with Timelog Depths) CD5-18 ConoeoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/14/2017 1/14/2017 0.50 COMPZ2 FISH OTHR T Make up stand#146 to single,Re-set 13,840.0 13,840.0 00:00 00:30 depth to 13,840.66'MD.Line up to pump down string to log RA tag.Start pumping and observe mud dripping from top drive.Shut down.Observed top drive not made up to string. 1/14/2017 1/14/2017 2.00 COMPZ2 FISH OTHR T Clean up/wipe down wind walls, 13,840.0 13,840.0 00:30 02:30 service loop,torque tube and rig floor of-5 gallon mud drips and mist spilled from top drive. SIMOPS-Line up MPD and monitor well,observe no static loss or gain. 1/14/2017 1/14/2017 0.25 COMPZ2 FISH SFTY T PJSM on plan forward,discuss good 13,840.0 13,840.0 02:30 02:45 changeout and first day back. 1/14/2017 1/14/2017 1.25 COMPZ2 FISH DLOG P Kelly up on stand#146,establish 13,840.0 13,935.0 02:45 04:00 circulation and sync with Impluse @ 200 gpm.Orient tool face to-37°L and slack off.Start logging 200 fph from 13,875'MD hook depth,log RA tag @ 13,846'MD with Impluse. (13,902'Hook depth). P/U=200k,S/0=130k. 1/14/2017 1/14/2017 1.00 COMPZ2 FISH FISH P Continue slowly in hole @-37°L(41°) 13,935.0 14,061.0 04:00 05:00 slack off and observe hook set down in slot @ 13,998'MD. Rotate 180°and jet slot 2x,return to-37°L and set down in slot.P/U and pulled 60k over firing jars,slipped off twice then stayed hooked. Pull 80k over and fire jars,observe whipstock release and pull up hole @ 205k. 1/14/2017 1/14/2017 0.50 COMPZ2 FISH OWFF P Shut down pump,(line up MPD to 14,061.0 14,061.0 05:00 05:30 cellar and observe well for flow,static. Rack back stand @ 14,061'MD. (Fish=130.37'long) 1/14/2017 1/14/2017 0.50 COMPZ2 FISH CIRC P Establish circulation @ 200 gpm, 1560 14,061.0 13,967.0 05:30 06:00 psi and begin to CBU,slowly pull stand#146,shut down pump and rack back to 13,967'to pull fish above window. 1/14/2017 1/14/2017 1.25 COMPZ2 FISH CIRC P Continue CBU @ 200 gpm, 1560 psi. 13,967.0 13,967.0 06:00 07:15 Obtain SPR's. 1/14/2017 1/14/2017 0.50 COMPZ2 FISH OWFF P Line up MPD to cellar and monitor well 13,967.0 13,967.0 07:15 07:45 for flow,-static.Pump 29 bbl, 11.0 ppg dry job.Blow down top drive,line up MPD to SOON. 1/14/2017 1/14/2017 0.25 COMPZ2 FISH PULD P Lay down single joint and pup joint to 13,967.0 13,922.0 07:45 08:00 pipe shed. 1/14/2017 1/14/2017 4.00 COMPZ2 FISH SMPD P Strip out of hole with MPD from 13,922.0 8,820.0 08:00 12:00 13,922'MD to 8,820'MD per stripping schedule. 120 psi pul;ling and 30 psi in slips.No 5/0 weights with whipstock,P/U=205k-160k. 1/14/2017 1/14/2017 5.50 COMPZ2 FISH SMPD P Continue stripping out of hole with 8,820.0 1,070.0 12:00 17:30 MPD from 8,820'MD to 1,070'MD per schedule,holding 80 psi pulling and 30 in slips.P/U=160k-75k. Page 33/38 Report Printed: 1/24/2017 Aerations Summary (with Timelog 6epths) Apr �.,._ CD5-18 F., 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) 1/14/2017 1/14/2017 0.50 COMPZ2 FISH OWFF P Line up MPD to cellar and observe 1,070.0 1,070.0 17:30 18:00 well for flow-Static SIMOPS-PJSM on pulling RCD and installing trip nipple. 1/14/2017 1/14/2017 0.50 COMPZ2 FISH MPDA P Blow down MPD system,pull RCD 1,070.0 1,070.0 18:00 18:30 and install trip nipple. 1/14/2017 1/14/2017 0.50 COMPZ2 FISH TRIP P POOH on elevators from 1,070'MD to 1,070.0 221.0 18:30 19:00 221'MD. P/U=70k. 1/14/2017 1/14/2017 2.50 COMPZ2 FISH BHAH P PJSM, LID fishing BHA and Whipstock 221.0 0.0 19:00 21:30 assembly to locator.One small chip off of hook indicating when hook slipped out of slot while fishing. Magnets 100%full.Observed no damage to whipstock or debris cup. Visible wear on RH side of tray.Post pictures on S drive. Calculated Fill for trip=78 bbl,Actual Fill=119 bbl. 1/14/2017 1/14/2017 1.50 COMPZ2 WELLPR BHAH P Clean and clear rig floor,lay down 0.0 0.0 21:30 23:00 fishing tools, RCD element.P/U Baker tools to rig floor for cleanout run. 1/14/2017 1/14/2017 0.50 COMPZ2 WELLPR SVRG P Service and inspect top drive,draw 0.0 0.0 23:00 23:30 works and iron roughneck.Service crown. 1/14/2017 1/15/2017 0.50 COMPZ2 WELLPR BHAH P PJSM,P/U cleanout assembly per 0.0 0.0 23:30 00:00 Baker rep.Build from jars down via 90' mousehole. OA pressure @ 23:00 hrs=30 psi Daily mud losses=72 bbl,Cumulative interval=594 bbl Static losses 1-3 bph. 1/15/2017 1/15/2017 0.75 COMPZ2 WELLPR BHAH P Continue M/U cleanout BHA per Baker 0.0 88.0 00:00 00:45 rep to 8'MD. 1/15/2017 1/15/2017 11.25 COMPZ2 WELLPR TRIP P RIH from 88'MD to 14,074'MD @ 88.0 14,074.0 00:45 12:00 5,000 fph,filling pipe every 20 stands. P/U=195k,S/0=130k.Calculated Disp=73.5 bbl,Actual Disp=41.5 bbl. 1/15/2017 1/15/2017 0.50 COMPZ2 WELLPR WASH P Break circulation and stage up to 300 14,074.0 14,143.0 12:00 12:30 gpm,2350 psi.Wash down from 14,074'MD to no-go @ 14,149'MD. Set down 5k,observe 100-150 psi pressure increase.Wipe mills across window x 3.P/U=200k,S/0=130k. 1/15/2017 1/15/2017 2.50 COMPZ2 WELLPR CIRC P Circulate and condition @ 300 gpm, 14,143.0 14,143.0 12:30 15:00 2280 psi. Pump 38 bbl HiVis sweep, reciprocate from 14,143'-14,123'MD. Pump total 3x BU. Page 34/38 Report Printed: 1/24/2017 Operations Summary (with TimelogDpths) CD5-18 conocophimps 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) 1/15/2017 1/15/2017 3.00 COMPZ2 WELLPR DISP P PJSM,displace well over to 9.2 ppg 14,143.0 14,143.0 15:00 18:00 brine as per plan.Pump 40 bbl Deepclean Hivis spacer,50 bbl Deepclean brine cleaning spacer from vac truck,40 bbl HiVis brine spacer from pill pit,followed by 720 bbl clean 9.2 ppg brine. ICP 1320 psi @ 6.5 bpm,FCP=750 psi @ 4.5 bpm. Monitor returns every 40 bbl pumped during displacement,5 bph dynamic losses. 1/15/2017 1/15/2017 1.25 COMPZ2 WELLPR CRIH P Pump 150 bbl 9.2 corrosion inhibited 14,143.0 14,143.0 18:00 19:15 brine(SBE to SOV+estimated losses.),displace balanced with 110 bbl 9.2 ppg neat brine. 1/15/2017 1/15/2017 0.75 COMPZ2 WELLPR TRIP P POOH on elevators from 14,143'MD 14,143.0 13,883.0 19:15 20:00 to 13,883'MD rack back stands in derrick. P/U=200k. Blow down top drive and mud lines. 1/15/2017 1/15/2017 1.50 COMPZ2 WELLPR SLPC P PJSM,cut and slip 68'of drilling line. 13,883.0 13,883.0 20:00 21:30 Calibrate block height. 1/15/2017 1/16/2017 2.50 COMPZ2 WELLPR PULD P PJSM,POOH laying down 4"DP from 13,883.0 11,777.0 21:30 00:00 13,883'MD to 11,777'MD.P/U=185k. Calc Fill=10 bbl,Actual Fill=14 bbl. OA pressure @ 23:00 hrs=0 psi. 1/16/2017 1/16/2017 12.00 COMPZ2 WELLPR PULD P POOH laying down 4"DP from 11,777.0 179.0 00:00 12:00 11,777'MD to 179'MD.Calc Fill=57.5 bbl,Actual Fill=86.5 bbl. Culled out 141 jts 14#DP for hardbanding and inspection/repair. 1/16/2017 1/16/2017 0.50 COMPZ2 WELLPR PULD P PJSM,POOH laying down 4"DP from 179.0 88.0 12:00 12:30 179'MD to 88'MD. 1/16/2017 1/16/2017 1.00 COMPZ2 WELLPR BHAH P Lay down cleanout BHA from 88'MD. 88.0 0.0 12:30 13:30 Clean and clear rig floor. 1/16/2017 1/16/2017 1.00 COMPZ2 WELLPR ELOG P Pull trip nipple,set 7"Otis E-line 0.0 0.0 13:30 14:30 adaptor in MPD flange for USIT logging. SIMOPS-Thaw lubricator extension. 1/16/2017 1/16/2017 0.50 COMPZ2 WELLPR ELOG P Rig up E-line 0.0 0.0 14:30 15:00 1/16/2017 1/16/2017 2.00 COMPZ2 WELLPR ELOG P Make up USIT logging tool string and 0.0 0.0 15:00 17:00 test. 1/16/2017 1/16/2017 3.00 COMPZ2 WELLPR ELOG P RIH with Eline,correlate and log up 0.0 0.0 17:00 20:00 from 4,162'MD GR/CCL/RB/USIT. Moderate/acceptable casing wear identified.Discuss with completion engineer and send log. Monitor well via MPD manifold,Otis valve and pump 1.Static losses-2 bph. 1/16/2017 1/16/2017 1.50 COMPZ2 WELLPR ELOG P Rig down eline logging tools and 0.0 0.0 20:00 21:30 equipment,release unit. 1/16/2017 1/16/2017 0.50 COMPZ2 WELLPR ELOG P Pull Otis adapter and set MPD cap, 0.0 0.0 21:30 22:00 close blind rams.Blow down MPD equipment and circulating lines.Pull cap and set trip nipple. Page 35/38 Report Printed: 1/24/2017 F tz Cs 0 * Operations Summary (with Timelog Depths) CD5-18 ....o.+a1'taimps Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/16/2017 1/17/2017 2.00 COMPZ2 RPCOMP RURD P PJSM,mobilize casing tools and 0.0 0.0 22:00 00:00 equipment, I-wire spool and tools to rig floor.Rig up to run tubing completion. OA pressure @ 22:00 hrs=0 psi Daily mud losses=52 bbl,Cumulative interval=67 bbl Static losses 1-3 bph. 1/17/2017 1/17/2017 1.50 COMPZ2 RPCOMP RURD P Continue rigging up tubing running 0.0 0.0 00:00 01:30 equipment.P/U clamps,hanger,XO's. Make up hole fill lines,rig up power tongs. 1/17/2017 1/17/2017 2.50 COMPZ2 RPCOMP PUTB P PJSM on running completion.P/U and 0.0 679.0 01:30 04:00 RIH with 3'/z'tubing completion per detail to 679'MD. P/U WLEG,Mirage plug,XN nipple,TNT p[acker#1, TN110 tubing,X nipple,sliding sleeve, TNT packer#2,X0 and SLB gauge carrier. S/0=70k. 1/17/2017 1/17/2017 1.00 COMPZ2 RPCOMP DHEQ P SLB tie in TEC wire to gauge carrier, 679.0 679.0 04:00 05:00 test to 5000 psi for 15 minutes,good. 1/17/2017 1/18/2017 19.00 COMPZ2 RPCOMP PUTB P RIH w/3 1/5"upper completion f/679' 679.0 9,386.0 05:00 00:00 to 9,386'MD as per tally while testing TEK wire every 2000'. S/0=98k 1/18/2017 1/18/2017 8.50 COMPZ2 RPCOMP PUTB P RIH w/3 1/5"upper completion f/ 9,386.0 14,109.0 00:00 08:30 9,386'to 14,109'MD as per tally while testing TEK wire every 2000'. S/O= 105, P/U=140. 1/18/2017 1/18/2017 0.25 COMPZ2 RPCOMP HOSO P M/U jnt#443 and S/0 to 14,112'MD 14,109.0 14,112.0 08:30 08:45 Located TOL and sheared locator screws with 12k down weight. 1/18/2017 1/18/2017 0.50 COMPZ2 RPCOMP HOSO P UD 3 jnt of tubing and space out w/ 14,112.0 14,112.0 08:45 09:15 2.25'3 1/2"pup,X0,and 4 1/2"jnt. 1/18/2017 1/18/2017 2.75 COMPZ2 RPCOMP THGR P M/U WR retrieval tool and retrieve 14,112.0 14,125.9 09:15 12:00 same. M/U 4 1/4"tubing hanger and landing joints. Terminate I-wire,test to 3508 psi,and land hanger at 14,125.88. 1/18/2017 1/18/2017 3.00 COMPZ2 RPCOMP THGR P RILDS,R/U test equipment and test 14,125.9 14,125.9 12:00 15:00 hanger seals to 250/5000 psi for 10 min. SimOps,R/U test lines. 1/18/2017 1/18/2017 3.00 COMPZ2 RPCOMP PRTS P Tested surface lines to 4200 psi then 14,125.9 14,125.9 15:00 18:00 built tubing pressure up to 500 psi and held for 5 min. Continued up to 4100 psi and held for 30 min(observed packers setting at 2400 and 2650 psi). Bleed tubing down to 1000 psi and pressure tested IA to 2400 psi for 30 min. Bleed off both IA and tubing. Attempted to shear SOV by pumping down the IA and observed flow through the tubing(SOV seared). pumped down tubing at 1.5 bpm for 3 bble and confirmed flow through IA with 210 psi. 1/18/2017 1/18/2017 1.00 COMPZ2 RPCOMP OWFF P Blow down and R/D test equipment. 14,125.9 14,125.9 18:00 19:00 UD landing joint and OWFF.Well Static. Page 36/38 Report Printed: 1/24/2017 Ag 4„ett5riv#iiiiikl,lic.,,, !perations Summary (with Timelog tpths) >t CD5-18 ConocoPhi lips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/18/2017 1/18/2017 1.25 COMPZ2 WHDBOP MPSP P UD landing joint and install HP-BPV 14,125.9 14,125.9 19:00 20:15 and test in direction of flow to 2400 psi for 15 min. 1/18/2017 1/18/2017 3.00 COMPZ2 WHDBOP WWWH P Cleaned under rotary table,drip pan, 14,125.9 14,125.9 20:15 23:15 flow box,B/D lines,and clear floor. Flushed stack and B/D mud lines. 1/18/2017 1/19/2017 0.75 COMPZ2 WHDBOP MPDA P Pulled trip nipple and started R/D 14,125.9 14,125.9 23:15 00:00 MPD equipment from the stack. 1/19/2017 1/19/2017 3.25 COMPZ2 WHDBOP NUND P Finish N/D RCD clamp,air valve and 14,125.9 14,125.9 00:00 03:15 katch can. Pull mouse hole and N/D BOPE and secure to stand. SimOps, changed out saver sub on TD. 1/19/2017 1/19/2017 2.75 COMPZ2 WHDBOP NUND P Installed smooth bore metal seal and 14,125.9 14,125.9 03:15 06:00 terminated TEC-Wire before N/U tree as per FMC.Tested TEC-Wire as per Camco. SimOps,UD completions running tools and clear rig floor. 1/19/2017 1/19/2017 2.25 COMPZ2 WHDBOP PRTS P Pressure test tree adapter void to 14,125.9 14,125.9 06:00 08:15 5000 psi and tested tree to 250/5000 psi for 10 min. Both tested were good. 1/19/2017 1/19/2017 0.75 COMPZ2 WHDBOP MPSP P R/U Lubricator and remove test dart 14,125.9 14,125.9 08:15 09:00 and BPV as per FMC. 1/19/2017 1/19/2017 1.00 COMPZ2 WHDBOP FRZP P R/U surface lines to freeze protect and 14,125.9 14,125.9 09:00 10:00 U-tube. tested lines to 2000 psi and held. 1/19/2017 1/19/2017 1.75 COMPZ2 WHDBOP FRZP P Freeze protect w/91 bbl of diesel 14,125.9 14,125.9 10:00 11:45 down the IA and taking brine returns up tubing at 2 bpm. ICP=449 psi, — FCP=759 psi. 1/19/2017 1/19/2017 0.75 COMPZ2 WHDBOP FRZP P Allow diesel to U-tube while B/D lines. 14,125.9 14,125.9 11:45 12:30 Initial pressure 205/305 psi on the IA/OA. Final pressures 150/100 psi on the IA/OA. 1/19/2017 1/19/2017 2.00 COMPZ2 WHDBOP MPSP P R/U Lubricator and install BPV. 14,125.9 14,125.9 12:30 14:30 Pressure tested against BPV in direction of flow to 2400 psi and held for 15 min. Test good. Well secure at 14:30 hrs. 1/19/2017 1/19/2017 1.50 DEMOB MOVE RURD P B/D lines and R/D test equipment 14,125.9 14,125.9 14:30 16:00 while cleaning and clearing floor. 1/19/2017 1/20/2017 8.00 DEMOB MOVE PULD P UD 4"15.7#DP from derrick while 14,125.9 14,125.9 16:00 00:00 removing WWT SS. Steaming connections as needed due to cold. 1/20/2017 1/20/2017 17.25 DEMOB MOVE PULD P L/D remaining 4"15.7#DP from 14,125.9 14,125.9 00:00 17:15 derrick while removing WWT SS. Steaming connections as needed due to cold. SimOps,move ball mill to new location. Rig on gen power @ 05:15 hrs 1/20/2017 1/20/2017 3.25 DEMOB MOVE GLEN P L/D WWT tools,clean pipe racks and 14,125.9 14,125.9 17:15 20:30 drip pans of residual OBM. Cut and cap mouse hole in the cellar. 1/20/2017 1/20/2017 1.25 DEMOB MOVE RURD P B/D H2O and steam lines. UD 4" 14,125.9 14,125.9 20:30 21:45 equipment and P/U 5"DP equipment to rig floor. Page 37/38 Report Printed: 1/24/2017 Operations Summary (with Timelog Depths) 11 &Wens CD5-18 +C€nocoPhiilips Al ack.3 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) 1/20/2017 1/21/2017 2.25 DEMOB MOVE MOB P Disconnect pipe shed f/sub. P/U 14,125.9 14,125.9 21:45 00:00 surface riser,continue clearing rig floor,and complete rig move check list. Release rig @ 00:00 hrs Page 38/38 Report Printed: 1/24/2017 • Cement Detail Report Draristi .1,4 &Wells CD5-18 CortocoPhiilips String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/30/2016 20:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/4/2016 00:35 12/4/2016 03:26 CD5-18 Comment Cemented with full returns. 183 bbls good cement to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 36.5 2,390.9 Yes 183.0 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 3 6 450.0 1,020.0 Yes 8.00 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 36.5 1,891.0 934 LiteCRETE 318.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) 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 1,891.0 2,391.0 240 G 57.9 Yield(fP/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 O 046 0.2 %BWOC Additive Type Concentration Conc Unit label O 065 0.3 %BWOC Additive Type Concentration Conc Unit label D167 0.4 %BWOC Page 1/1 Report Printed: 1/24/2017 , 0 e • - Cement Detail Report Driig .14 CD5-18 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 11/30/2016 20:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/16/2016 22:45 12/17/2016 05:30 CD5-18 Comment Cemented two stage job with full returns.40 bbl Mud Push ahead of each stage. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement intermediate, 12,796.0 15,250.0 Yes Yes Yes Cement 500'above Kup C 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 7 750.0 1,300.0 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 12,796.0 15,263.0 1,036 G 215.7 Yield(f/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 15.80 128.0 6.00 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 Isolate Qannik,500' 5,650.0 6,350.0 Yes Yes No Cement above 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) 3 8 7 360.0 1,500.0 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 5,650.0 6,350.0 276 G 57.6 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 15.80 143.0 4.75 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 Page 1/1 Report Printed: 1/24/2017 . • NADConversion Western North Slope CD5 Alpine West Pad CD5-18 CD5-18 Definitive Survey Report 31 January, 2017 • SLB 0 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-18 Well Position +NI-S 0.00 usft Northing: 5,965,823.83 usft Latitude: 70°18'49.398 N +E/-W 0.00 usft Easting: 349,212.08 usft Longitude: 151°13'19.556 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.90 usft Wellbore CD5-18 Magftetleft Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BG GM 2016 11/21/2016 17.44 80.81 57,508 Design CD5-18 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.90 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 36.90 0.00 0.00 152.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 84.00 356.00 CD5-18 Svy1 SLB_GWD70(CD5-18) GYD-GC-SS Gyrodata gyro single shots 12/1/2016 12:59 385.12 2,324.62 CD5-18 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/1/2016 9:00: 2,358.13 2,358.13 CD5-18 Svy3-SLB_INC+Filler(CD5-18) INC+TREND Inclinometer+known azi trend 12/5/2016 9:36: 2,453.27 15,197.97 CD5-18 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/5/2016 9:40: 15,292.25 27,027.60 CD5-18 Svy5-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/19/2016 8:24 Survey Map Map Vertical MD Inc Azi TVD T1fDSS +NJ-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) {usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 36.90 0.00 0.00 36.90 -33.90 0.00 0.00 5,965,823.83 349,212.08 0.00 0.00 UNDEFINED 84.00 0.33 76.87 84.00 13.20 0.03 0.13 5,965,823.86 349,212.21 0.70 0.03 GYD-GC-SS(1) 115.00 0.56 29.85 115.00 44.20 0.18 0.29 5,965,824.01 349,212.38 1.33 -0.02 GYD-GC-SS(1) 115.90 0.55 30.98 115.90 45.10 0.19 0.30 5,965,824.01 349,212.38 1.67 -0.03 GYD-GC-SS(1) 20"x 42" 171.00 0.68 127.23 171.00 100.20 0.22 0.70 5,965,824.04 349,212.78 1.67 0.13 GYD-GC-SS(1) 264.00 3.85 163.47 263.91 193.11 -3.11 2.02 5,965,820.68 349,214.04 3.58 3.70 GYD-GC-SS(1) 356.00 5.42 171.91 355.61 284.81 -10.37 3.51 5,965,813.39 349,215.38 1.86 10.81 GYD-GC-SS(1) 385.12 5.16 171.93 384.61 313.81 -13.03 3.89 5,965,810.73 349,215.71 0.89 13.33 MWD+IFR-AK-CAZ-SC(2) 477.47 5.47 175.37 476.56 405.76 -21.53 4.83 5,965,802.21 349,216.47 0.48 21.28 MWD+IFR-AK-CAZ-SC(2) 568.24 9.11 174.42 566.58 495.78 -33.00 5.88 5,965,790.72 349,217.29 4.01 31.89 MWD+IFR-AK-CAZ-SC(2) 1/31/2017 4:45:04PM Page 2 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope ND Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD NDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 661.05 9.36 171.33 658.19 587.39 -47.77 7.73 5,965,775.92 349,218.85 0.60 45.81 MWD+IFR-AK-CAZ-SC(2) 751.80 10.03 170.95 747.64 676.84 -62.87 10.09 5,965,760.77 349,220.90 0.74 60.25 MWD+IFR-AK-CAZ-SC(2) 845.91 11.75 171.62 840.05 769.25 -80.45 12.77 5,965,743.15 349,223.23 1.83 77.02 MWD+IFR-AK-CAZ-SC(2) 940.18 12.80 166.75 932.17 861.37 -100.11 16.56 5,965,723.42 349,226.63 1.56 96.17 MWD+IFR-AK-CAZ-SC(2) 1,032.91 14.02 165.87 1,022.37 951.57 -121.00 21.66 5,965,702.43 349,231.30 1.33 117.01 MWD+IFR-AK-CAZ-SC(2) 1,126.89 15.56 165.25 1,113.23 1,042.43 -144.23 27.65 5,965,679.09 349,236.82 1.65 140.33 MWD+IFR-AK-CAZ-SC(2) 1,221.55 16.73 165.69 1,204.16 1,133.36 -169.71 34.25 5,965,653.48 349,242.91 1.24 165.92 MWD+IFR-AK-CAZ-SC(2) 1,315.85 20.07 164.25 1,293.63 1,222.83 -198.44 42.00 5,965,624.60 349,250.08 3.57 194.93 MWD+IFR-AK-CAZ-SC(2) 1,410.44 21.30 161.77 1,382.12 1,311.32 -230.38 51.78 5,965,592.47 349,259.22 1.60 227.72 MWD+IFR-AK-CAZ-SC(2) 1,504.77 25.42 157.37 1,468.71 1,397.91 -265.36 64.94 5,965,557.24 349,271.67 4.74 264.78 MWD+IFR-AK-CAZ-SC(2) 1,599.01 27.63 156.00 1,553.02 1,482.22 -304.00 81.61 5,965,518.28 349,287.56 2.43 306.73 MWD+IFR-AK-CAZ-SC(2) 1,692.54 28.46 155.81 1,635.57 1,564.77 -344.14 99.56 5,965,477.79 349,304.70 0.89 350.60 MWD+IFR-AK-CAZ-SC(2) 1,786.51 31.35 151.26 1,717.03 1,646.23 -386.01 120.50 5,965,435.51 349,324.79 3.91 397.40 MWD+IFR-AK-CAZ-SC(2) 1,878.21 34.95 149.01 1,793.79 1,722.99 -429.46 145.50 5,965,391.57 349,348.92 4.15 447.50 MWD+IFR-AK-CAZ-SC(2) 1,972.67 36.98 147.62 1,870.24 1,799.44 -476.65 174.65 5,965,343.80 349,377.11 2.32 502.85 MWD+IFR-AK-CAZ-SC(2) 2,066.79 38.40 145.66 1,944.73 1,873.93 -524.70 206.30 5,965,295.13 349,407.79 1.97 560.14 MWD+IFR-AK-CAZ-SC(2) 2,161.07 40.73 142.85 2,017.41 1,946.61 -573.41 241.40 5,965,245.74 349,441.90 3.12 619.62 MWD+IFR-AK-CAZ-SC(2) 2,253.23 41.56 137.78 2,086.83 2,016.03 -620.02 280.11 5,965,198.35 349,479.66 3.73 678.95 MWD+IFR-AK-CAZ-SC(2) 2,324.62 42.97 136.72 2,139.66 2,068.86 -655.27 312.71 5,965,162.46 349,511.54 2.21 725.38 MVVD+IFR-AK-CAZ-SC(2) 2,358.13 43.68 136.32 2,164.03 2,093.23 -671.96 328.53 5,965,145.46 349,527.02 2.27 747.54 INC+TREND(3) 2,390.93 44.08 135.97 2,187.68 2,116.88 -688.35 344.28 5,965,128.75 349,542.44 1.43 769.41 MWD+IFR-AK-CAZ-SC(4) 10414"x 13-112" 2,453.27 44.85 135.33 2,232.17 2,161.37 -719.58 374.81 5,965,096.92 349,572.33 1.43 811.31 MWD+IFR-AK-CAZ-SC(4) 2,546.73 46.88 134.63 2,297.24 2,226.44 -766.98 422.26 5,965,048.58 349,618.82 2.24 875.44 MWD+IFR-AK-CAZ-SC(4) 2,641.67 50.17 131.46 2,360.12 2,289.32 -815.48 474.26 5,964,999.05 349,669.83 4.27 942.68 MWD+IFR-AK-CAZ-SC(4) 2,736.93 53.19 129.73 2,419.18 2,348.38 -864.09 531.01 5,964,949.32 349,725.59 3.48 1,012.24 MWD+IFR-AK-CAZ-SC(4) 2,830.92 55.73 127.99 2,473.82 2,403.02 -912.05 590.57 5,964,900.17 349,784.17 3.09 1,082.55 MWD+IFR-AK-CAZ-SC(4) 2,924.89 58.53 126.10 2,524.82 2,454.02 -959.58 653.56 5,964,851.40 349,846.19 3.43 1,154.09 MWD+IFR-AK-CAZ-SC(4) 3,020.04 61.73 124.85 2,572.20 2,501.40 -1,007.44 720.76 5,964,802.19 349,912.41 3.55 1,227.89 MWD+IFR-AK-CAZ-SC(4) 3,114.60 61.75 124.85 2,616.97 2,546.17 -1,055.04 789.11 5,964,753.24 349,979.78 0.02 1,302.00 MWD+IFR-AK-CAZ-SC(4) 3,209.57 61.67 125.50 2,661.98 2,591.18 -1,103.21 857.46 5,964,703.71 350,047.15 0.61 1,376.63 MWD+IFR-AK-CAZ-SC(4) 3,304.00 61.66 125.69 2,706.80 2,636.00 -1,151.59 925.05 5,964,653.98 350,113.75 0.18 1,451.08 MWD+IFR-AK-CAZ-SC(4) 3,397.53 62.14 125.78 2,750.85 2,680.05 -1,199.77 992.02 5,964,604.47 350,179.73 0.52 1,525.06 MVVD+IFR-AK-CAZ-SC(4) 3,492.38 62.16 126.38 2,795.16 2,724.36 -1,249.16 1,059.80 5,964,553.73 350,246.50 0.56 1,600.49 MWD+IFR-AK-CAZ-SC(4) 3,586.20 62.06 127.05 2,839.05 2,768.25 -1,298.74 1,126.27 5,964,502.84 350,311.96 0.64 1,675.47 MWD+IFR-AK-CAZ-SC(4) 3,680.61 62.26 126.72 2,883.14 2,812.34 -1,348.84 1,193.04 5,964,451.40 350,377.71 0.37 1,751.06 MWD+IFR-AK-CAZ-SC(4) 3,775.49 62.22 127.74 2,927.33 2,856.53 -1,399.64 1,259.89 5,964,399.28 350,443.52 0.95 1,827.29 MWD+IFR-AK-CAZ-SC(4) 3,869.92 62.19 128.32 2,971.37 2,900.57 -1,451.10 1,325.69 5,964,346.51 350,508.26 0.54 1,903.62 MWD+IFR-AK-CAZ-SC(4) 3,964.06 62.23 127.97 3,015.26 2,944.46 -1,502.54 1,391.19 5,964,293.77 350,572.71 0.33 1,979.79 MWD+IFR-AK-CAZ-SC(4) 4,058.87 62.20 127.39 3,059.45 2,988.65 -1,553.81 1,457.57 5,964,241.18 350,638.05 0.54 2,056.22 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 3 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!$ +E/W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l1001 (ft) Survey Tool Name 4,152.20 61.92 127.74 3,103.18 3,032.38 -1,604.08 1,522.93 5,964,189.61 350,70238 0.45 2,131 29 MWD+IFR-AK-CAZ-SC(4) 4,245.68 62.20 127.38 3,146.98 3,076.18 -1,654.42 1,588.39 5,964,137.97 350,766.81 0.45 2,206.47 MWD+IFR-AK-CAZ-SC(4) 4,340.73 62.59 127.00 3,191.03 3,120.23 -1,705.33 1,655.49 5,964,085.72 350,832.87 0.54 2,282.93 MWD+IFR-AK-CAZ-SC(4) 4,433.27 62.66 126.08 3,233.58 3,162.78 -1,754.26 1,721.52 5,964,035.49 350,897.89 0.89 2,357.12 MWD+IFR-AK-CAZ-SC(4) 4,527.69 62.51 124.82 3,277.06 3,206.26 -1,802.87 1,789.79 5,963,985.52 350,965.18 1.20 2,432.10 MWD+IFR-AK-CAZ-SC(4) 4,622.57 62.52 123.88 3,320.84 3,250.04 -1,850.36 1,859.28 5,963,936.64 351,033.69 0.88 2,506.66 MWD+IFR-AK-CAZ-SC(4) 4,716.91 62.66 122.99 3,364.28 3,293.48 -1,896.51 1,929.17 5,963,889.11 351,102.64 0.85 2,580.21 MWD+IFR-AK-CAZ-SC(4) 4,809.25 62.65 123.34 3,406.69 3,335.89 -1,941.38 1,997.83 5,963,842.87 351,170.38 0.34 2,652.06 MWD+IFR-AK-CAZ-SC(4) 4,903.70 62.71 123.35 3,450.04 3,379.24 -1,987.50 2,067.93 5,963,795.35 351,239.53 0.06 2,725.70 MWD+IFR-AK-CAZ-SC(4) 4,996.61 62.65 124.29 3,492.68 3,421.88 -2,033.45 2,136.51 5,963,748.04 351,307.17 0.90 2,798.46 MWD+IFR-AK-CAZ-SC(4) 5,090.38 62.64 125.01 3,535.77 3,464.97 -2,080.80 2,205.02 5,963,699.33 351,374.71 0.68 2,872.43 MWD+IFR-AK-CAZ-SC(4) 5,184.83 62.71 126.11 3,579.13 3,508.33 -2,129.60 2,273.28 5,963,649.17 351,441.97 1.04 2,947.57 MWD+IFR-AK-CAZ-SC(4) 5,279.37 62.77 126.26 3,622.43 3,551.63 -2,179.21 2,341.11 5,963,598.21 351,508.79 0.15 3,023.22 MWD+IFR-AK-CAZ-SC(4) 5,373.39 62.52 127.28 3,665.63 3,594.83 -2,229.20 2,408.01 5,963,546.89 351,574.66 1.00 3,098.76 MWD+IFR-AK-CAZ-SC(4) 5,466.99 62.68 127.56 3,708.71 3,637.91 -2,279.70 2,474.00 5,963,495.08 351,639.62 0.32 3,174.33 MWD+IFR-AK-CAZ-SC(4) 5,561.53 62.61 127.51 3,752.15 3,681.35 -2,330.85 2,540.59 5,963,442.60 351,705.16 0.09 3,250.76 MWD+IFR-AK-CAZ-SC(4) 5,656.00 62.58 127.23 3,795.63 3,724.83 -2,381.76 2,607.24 5,963,390.37 351,770.77 0.27 3,326.99 MWD+IFR-AK-CAZ-SC(4) 5,748.79 62.64 126.73 3,838.32 3,767.52 -2,431.32 2,673.06 5,963,339.51 351,835.58 0.48 3,401.65 MWD+IFR-AK-CAZ-SC(4) 5,843.84 62.78 125.93 3,881.90 3,811.10 -2,481.36 2,741.11 5,963,288.11 351,902.60 0.76 3,477.78 MWD+IFR-AK-CAZ-SC(4) 5,937.70 62.68 124.56 3,924.91 3,854.11 -2,529.50 2,809.24 5,963,238.61 351,969.75 1.30 3,552.28 MWD+IFR-AK-CAZ-SC(4) 6,031.84 62.71 124.40 3,968.09 3,897.29 -2,576.86 2,878.19 5,963,189.89 352,037.73 0.15 3,626.46 MWD+IFR-AK-CAZ-SC(4) 6,126.23 62.68 125.29 4,011.39 3,940.59 -2,624.78 2,947.03 5,963,140.60 352,105.59 0.84 3,701.09 MWD+IFR-AK-CAZ-SC(4) 6,220.52 62.75 125.14 4,054.62 3,983.82 -2,673.10 3,015.49 5,963,090.91 352,173.06 0.16 3,775.90 MWD+IFR-AK-CAZ-SC(4) 6,315.29 62.74 125.30 4,098.02 4,027.22 -2,721.69 3,084.32 5,963,040.96 352,240.89 0.15 3,851.11 MWD+IFR-AK-CAZ-SC(4) 6,410.03 62.68 125.64 4,141.45 4,070.65 -2,770.54 3,152.89 5,962,990.74 352,308.46 0.33 3,926.44 MWD+IFR-AK-CAZ-SC(4) 6,504.45 62.75 126.69 4,184.74 4,113.94 -2,820.06 3,220.63 5,962,939.87 352,375.19 0.99 4,001.96 MWD+IFR-AK-CAZ-SC(4) 6,597.88 62.69 127.68 4,227.56 4,156.76 -2,870.25 3,286.79 5,962,888.37 352,440.32 0.94 4,077.33 MWD+IFR-AK-CAZ-SC(4) 6,692.85 62.69 128.27 4,271.13 4,200.33 -2,922.17 3,353.31 5,962,835.13 352,505.78 0.55 4,154.41 MWD+IFR-AK-CAZ-SC(4) 6,786.89 62.65 127.74 4,314.31 4,243.51 -2,973.61 3,419.13 5,962,782.38 352,570.56 0.50 4,230.73 MWD+IFR-AK-CAZ-SC(4) 6,881.59 62.64 128.01 4,357.82 4,287.02 -3,025.25 3,485.53 5,962,729.42 352,635.89 0.25 4,307.49 MWD+IFR-AK-CAZ-SC(4) 6,975.69 62.65 128.04 4,401.06 4,330.26 -3,076.74 3,551.36 5,962,676.63 352,700.68 0.03 4,383.86 MWD+IFR-AK-CAZ-SC(4) 7,070.09 62.69 127.29 4,444.41 4,373.61 -3,127.98 3,617.75 5,962,624.07 352,766.02 0.71 4,460.27 MWD+IFR-AK-CAZ-SC(4) 7,165.37 62.72 126.10 4,488.10 4,417.30 -3,178.57 3,685.64 5,962,572.12 352,832.87 1.11 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,259.17 62.62 125.76 4,531.16 4,460.36 -3,227.47 3,753.11 5,962,521.89 352,899.35 0.34 4,611.67 MWD+IFR-AK-CAZ-SC(4) 7,354.03 62.19 125.10 4,575.11 4,504.31 -3,276.21 3,821.61 5,962,471.79 352,966.85 0.77 4,686.86 MWD+IFR-AK-CAZ-SC(4) 7,447.25 62.17 124.98 4,618.61 4,547.81 -3,323.54 3,889.12 5,962,423.11 353,033.38 0.12 4,760.34 MVVD+IFR-AK-CAZ-SC(4) 7,541.72 62.23 124.33 4,662.67 4,591.87 -3,371.06 3,957.86 5,962,374.22 353,101.15 0.61 4,834.57 M1ND+IFR-AK-CAZ-SC(4) 7,636.59 62.23 124.26 4,706.87 4,636.07 -3,418.36 4,027.21 5,962,325.55 353,169.53 0.07 4,908.89 MWD+IFR-AK-CAZ-SC(4) 7,730.82 62.22 125.34 4,750.78 4,679.98 -3,465.94 4,095.67 5,962,276.60 353,237.02 1.01 4,983.04 MWD+IFR-AK-CAZ-SC(4) 7,824.87 62.23 126.24 4,794.61 4,723.81 -3,514.60 4,163.17 5,962,226.60 353,303.52 0.85 5,057.70 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 4 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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) (°/1001 (ft) Survey Tool Name 7,920.41 62.17 126.71 4,839.17 4,768.37 -3,564.84 4,231.12 5,962,175.01 353,370.45 0.44 5,133.96 MWD+IFR-AK-CAZ-SC(4) 8,015.16 62.14 126.65 4,883.43 4,812.63 -3,614.89 4,298.31 5,962,123.63 353,436.62 0.06 5,209.69 MWD+IFR-AK-CAZ-SC(4) 8,108.34 62.17 126.43 4,926.95 4,856.15 -3,663.94 4,364.51 5,962,073.26 353,501.81 0.21 5,284.08 MWD+IFR-AK-CAZ-SC(4) 8,201.17 62.19 126.06 4,970.27 4,899.47 -3,712.48 4,430.72 5,962,023.40 353,567.03 0.35 5,358.03 MWD+IFR-AK-CAZ-SC(4) 8,295.29 62.16 125.59 5,014.21 4,943.41 -3,761.20 4,498.21 5,961,973.34 353,633.52 0.44 5,432.73 MWD+IFR-AK-CAZ-SC(4) 8,389.10 62.14 125.89 5,058.03 4,987.23 -3,809.65 4,565.54 5,961,923.55 353,699.86 0.28 5,507.11 MWD+IFR-AK-CAZ-SC(4) 8,483.45 62.13 125.36 5,102.13 5,031.33 -3,858.24 4,633.34 5,961,873.62 353,766.66 0.50 5,581.84 MWD+IFR-AK-CAZ-SC(4) 8,576.79 62.23 124.44 5,145.69 5,074.89 -3,905.47 4,701.04 5,961,825.04 353,833.40 0.88 5,655.33 MWD+IFR-AK-CAZ-SC(4) 8,671.18 62.28 124.61 5,189.63 5,118.83 -3,952.81 4,769.86 5,961,776.32 353,901.25 0.17 5,729.44 MWD+IFR-AK-CAZ-SC(4) 8,765.50 62.69 124.88 5,233.21 5,162.41 -4,000.49 4,838.60 5,961,727.28 353,969.01 0.50 5,803.81 MWD+IFR-AK-CAZ-SC(4) 8,859.72 62.73 125.83 5,276.41 5,205.61 -4,048.94 4,906.89 5,961,677.47 354,036.31 0.90 5,878.65 MWD+IFR-AK-CAZ-SC(4) 8,953.36 62.68 125.97 5,319.35 5,248.55 -4,097.73 4,974.30 5,961,627.34 354,102.72 0.14 5,953.38 MWD+IFR-AK-CAZ-SC(4) 9,047.60 62.63 126.61 5,362.64 5,291.84 -4,147.28 5,041.77 5,961,576.45 354,169.18 0.61 6,028.80 MWD+IFR-AK-CAZ-SC(4) 9,142.34 62.65 125.31 5,406.18 5,335.38 -4,196.69 5,109.87 5,961,525.69 354,236.27 1.22 6,104.39 MWD+IFR-AK-CAZ-SC(4) 9,236.31 62.64 124.96 5,449.36 5,378.56 -4,244.72 5,178.13 5,961,476.30 354,303.54 0.33 6,178.85 MWD+IFR-AK-CAZ-SC(4) 9,329.94 62.72 125.21 5,492.33 5,421.53 -4,292.53 5,246.20 5,961,427.13 354,370.63 0.25 6,253.02 MWD+IFR-AK-CAZ-SC(4) 9,423.56 62.62 124.36 5,535.31 5,464.51 -4,339.98 5,314.51 5,961,378.33 354,437.97 0.81 6,326.99 MWD+IFR-AK-CAZ-SC(4) 9,518.44 62.65 124.55 5,578.93 5,508.13 -4,387.65 5,383.99 5,961,329.27 354,506.47 0.18 6,401.70 MWD+IFR-AK-CAZ-SC(4) 9,613.17 62.72 124.33 5,622.40 5,551.60 -4,435.25 5,453.40 5,961,280.29 354,574.91 0.22 6,476.31 MWD+IFR-AK-CAZ-SC(4) 9,707.49 62.58 124.36 5,665.73 5,594.93 -4,482.52 5,522.57 5,961,231.65 354,643.11 0.15 6,550.52 MWD+IFR-AK-CAZ-SC(4) 9,801.90 62.72 124.09 5,709.10 5,638.30 -4,529.68 5,591.91 5,961,183.11 354,711.48 0.29 6,624.71 MWD+IFR-AK-CAZ-SC(4) 9,895.12 62.71 125.15 5,751.84 5,681.04 -4,576.75 5,660.08 5,961,134.68 354,778.70 1.01 6,698.28 MWD+IFR-AK-CAZ-SC(4) 9,989.24 62.85 125.63 5,794.89 5,724.09 -4,625.22 5,728.32 5,961,084.85 354,845.94 0.48 6,773.11 MWD+IFR-AK-CAZ-SC(4) 10,081 30 62.75 127.14 5,836.97 5,766.17 -4,673.79 5,794.23 5,961,034.97 354,910.86 1.46 6,846.94 MWD+IFR-AK-CAZ-SC(4) 10,175.34 62.79 127.04 5,880.00 5,809.20 -4,724.22 5,860.93 5,960,983.22 354,976.53 0.10 6,922.78 MWD+IFR-AK-CAZ-SC(4) 10,269.23 62.79 126.86 5,922.93 5,852.13 -4,774.41 5,927.66 5,960,931.70 355,042.23 0.17 6,998.43 MWD+IFR-AK-CAZ-SC(4) 10,363.59 62.59 127.69 5,966.23 5,895.43 -4,825.19 5,994.38 5,960,879.60 355,107.91 0.81 7,074.58 MVVD+IFR-AK-CAZ-SC(4) 10,455.95 62.70 127.43 6,008.67 5,937.87 -4,875.20 6,059.41 5,960,828.30 355,171.92 0.28 7,149.26 MWD+IFR-AK-CAZ-SC(4) 10,550.12 62.65 126.87 6,051.89 5,981.09 -4,925.72 6,126.09 5,960,776.45 355,237.57 0.53 7,225.18 MWD+IFR-AK-CAZ-SC(4) 10,643.93 62.55 126.37 6,095.07 6,024.27 -4,975.40 6,192.93 5,960,725.44 355,303.40 0.49 7,300.42 MWD+IFR-AK-CAZ-SC(4) 10,738.33 62.62 126.27 6,138.53 6,067.73 -5,025.03 6,260.45 5,960,674.47 355,369.90 0.12 7,375.95 MWD+IFR-AK-CAZ-SC(4) 10,831.70 62.66 126.53 6,181.44 6,110.64 -5,074.24 6,327.20 5,960,623.93 355,435.64 0.25 7,450.73 MWD+IFR-AK-CAZ-SC(4) 10,924.78 62.70 125.50 6,224.16 6,153.36 -5,122.87 6,394.09 5,960,573.98 355,501.53 0.98 7,525.07 MWD+IFR-AK-CAZ-SC(4) 11,019.12 62.69 126.13 6,267.44 6,196.64 -5,171.92 6,462.07 5,960,523.57 355,568.51 0.59 7,600.29 MWD+IFR-AK-CAZ-SC(4) 11,113.38 62.15 126.32 6,311.08 6,240.28 -5,221.30 6,529.46 5,960,472.86 355,634.89 0.60 7,675.53 MWD+IFR-AK-CAZ-SC(4) 11,205.90 62.24 126.56 6,354.24 6,283.44 -5,269.91 6,595.30 5,960,422.94 355,699.74 0.25 7,749.36 MWD+IFR-AK-CAZ-SC(4) 11,300.07 62.13 127.17 6,398.18 6,327.38 -5,319.87 6,661.94 5,960,371.65 355,765.35 0.58 7,824.76 MWD+IFR-AK-CAZ-SC(4) 11,393.17 62.20 126.83 6,441.65 6,370.85 -5,369.42 6,727.69 5,960,320.80 355,830.09 0.33 7,899.37 MWD+IFR-AK-CAZ-SC(4) 11,486.75 62.17 126.57 6,485.32 6,414.52 -5,418.88 6,794.05 5,960,270.01 355,895.44 0.25 7,974.20 MWD+IFR-AK-CAZ-SC(4) 11,580.56 62.20 127.18 6,529.09 6,458.29 -5,468.67 6,860.42 5,960,218.91 355,960.79 0.58 8,049.32 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 5 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,674.78 62.27 127.64 6,572.98 6,502.18 -5,519.32 6,926.64 5,960,166.94 356,025.98 0.44 8,125.13 MWD+IFR-AK-CAZ-SC(4) 11,768.18 62.34 128.29 6,616.39 6,545.59 -5,570.20 6,991.84 5,960,114.77 356,090.14 0.62 8,200.66 MWD+IFR-AK-CAZ-SC(4) 11,862.91 62.14 129.15 6,660.51 6,589.71 -5,622.63 7,057.24 5,960,061.04 356,154.47 0.83 8,277.66 MWD+IFR-AK-CAZ-SC(4) 11,956.92 62.20 128.64 6,704.40 6,633.60 -5,674.83 7,121.95 5,960,007.55 356,218.11 0.48 8,354.13 MWD+IFR-AK-CAZ-SC(4) 12,049.21 62.18 128.64 6,747.46 6,676.66 -5,725.80 7,185.71 5,959,955.31 356,280.83 0.02 8,429.07 MWD+IFR-AK-CAZ-SC(4) 12,142.96 62.21 129.84 6,791.19 6,720.39 -5,778.26 7,249.93 5,959,901.58 356,343.98 1.13 8,505.54 MWD+IFR-AK-CAZ-SC(4) 12,236.77 62.58 130.38 6,834.66 6,763.86 -5,831.81 7,313.51 5,959,846.76 356,406.47 0.64 8,582.67 MWD+IFR-AK-CAZ-SC(4) 12,330.84 62.63 130.52 6,877.95 6,807.15 -5,886.00 7,377.07 5,959,791.32 356,468.92 0.14 8,660.35 MWD+IFR-AK-CAZ-SC(4) 12,424.49 62.66 132.26 6,920.98 6,850.18 -5,940.99 7,439.47 5,959,735.08 356,530.19 1.65 8,738.20 MWD+IFR-AK-CAZ-SC(4) 12,518.25 62.69 132.98 6,964.02 6,893.22 -5,997.40 7,500.76 5,959,677.47 356,590.34 0.68 8,816.78 MWD+IFR-AK-CAZ-SC(4) 12,611.31 62.62 133.38 7,006.77 6,935.97 -6,053.96 7,561.04 5,959,619.71 356,649.46 0.39 8,895.02 MWD+IFR-AK-CAZ-SC(4) 12,705.28 62.56 134.18 7,050.03 6,979.23 -6,111.68 7,621.27 5,959,560.80 356,708.52 0.76 8,974.26 MWD+IFR-AK-CAZ-SC(4) 12,798.86 62.41 133.92 7,093.26 7,022.46 -6,169.38 7,680.92 5,959,501.91 356,766.99 0.29 9,053.22 MWD+IFR-AK-CAZ-SC(4) 12,892.88 62.38 134.29 7,136.83 7,066.03 -6,227.37 7,740.75 5,959,442.74 356,825.64 0.35 9,132.50 MWD+IFR-AK-CAZ-SC(4) 12,986.81 63.09 134.50 7,179.86 7,109.06 -6,285.78 7,800.40 5,959,383.14 356,884.11 0.78 9,212.09 MWD+IFR-AK-CAZ-SC(4) 13,080.34 63.18 134.12 7,222.12 7,151.32 -6,344.07 7,860.11 5,959,323.68 356,942.63 0.37 9,291.58 MWD+IFR-AK-CAZ-SC(4) 13,174.14 64.60 135.30 7,263.40 7,192.60 -6,403.32 7,919.96 5,959,263.23 357,001.27 1.89 9,371.99 MWD+IFR-AK-CAZ-SC(4) 13,268.65 65.84 136.73 7,303.02 7,232.22 -6,465.06 7,979.54 5,959,200.31 357,059.60 1.90 9,454.48 MWD+IFR-AK-CAZ-SC(4) 13,361.45 67.88 137.74 7,339.48 7,268.68 -6,527.71 8,037.48 5,959,136.52 357,116.26 2.42 9,536.99 MWD+IFR-AK-CAZ-SC(4) 13,455.04 70.12 138.25 7,373.02 7,302.22 -6,592.63 8,095.94 5,959,070.44 357,173.40 2.45 9,621.77 MWD+IFR-AK-CAZ-SC(4) 13,549.20 72.03 139.62 7,403.56 7,332.76 -6,659.79 8,154.44 5,959,002.13 357,230.54 2.45 9,708.52 MWD+IFR-AK-CAZ-SC(4) 13,643.10 73.37 141.03 7,431.48 7,360.68 -6,728.79 8,211.67 5,958,932.00 357,286.37 2.02 9,796.32 MWD+IFR-AK-CAZ-SC(4) 13,738.19 75.03 142.52 7,457.38 7,386.58 -6,800.67 8,268.28 5,958,859.00 357,341.52 2.31 9,886.36 MWD+IFR-AK-CAZ-SC(4) 13,830.52 76.88 143.97 7,479.78 7,408.98 -6,872.43 8,321.87 5,958,786.19 357,393.65 2.52 9,974.88 MWD+IFR-AK-CAZ-SC(4) 13,924.72 79.22 145.65 7,499.29 7,428.49 -6,947.74 8,374.97 5,958,709.83 357,445.22 3.04 10,066.30 MVVD+IFR-AK-CAZ-SC(4) 14,018.68 81.68 146.65 7,514.88 7,444.08 -7,024.69 8,426.58 5,958,631.87 357,495.27 2.82 10,158.47 MWD+IFR-AK-CAZ-SC(4) 14,113.21 83.32 146.90 7,527.21 7,456.41 -7,103.09 8,477.93 5,958,552.46 357,545,03 1.75 10,251.80 MWD+IFR-AK-CAZ-SC(4) 14,204.97 84.50 149.24 7,536.95 7,466.15 -7,180.52 8,526.18 5,958,474.08 357,591.71 2.84 10,342.82 MWD+IFR-AK-CAZ-SC(4) 14,299.09 84.99 150.16 7,545.57 7,474.77 -7,261.44 8,573.46 5,958,392.23 357,637.36 1.10 10,436.47 MWD+IFR-AK-CAZ-SC(4) 14,393.31 85.21 150.93 7,553.62 7,482.82 -7,343.18 8,619.62 5,958,309.59 357,681.87 0.85 10,530.31 MWD+IFR-AK-CAZ-SC(4) 14,487.43 84.36 150.55 7,562.17 7,491.37 -7,424.95 8,665.44 5,958,226.92 357,726.03 0.99 10,624.02 MWD+IFR-AK-CAZ-SC(4) 14,580.27 84.56 149.74 7,571 14 7,500.34 -7,505.09 8,711.44 5,958,145.88 357,770.40 0.89 10,716.37 MWD+IFR-AK-CAZ-SC(4) 14,674.94 84.36 148.61 7,580.28 7,509.48 -7,586.01 8,759.72 5,958,064.01 357,817.05 1.21 10,810.49 MWD+IFR-AK-CAZ-SC(4) 14,767.23 84.00 147.75 7,589.63 7,518.83 -7,664.02 8,808.13 5,957,985.05 357,863.88 1.01 10,902.09 MWD+IFR-AK-CAZ-SC(4) . 14,861.19 84.00 148.38 7,599.46 7,528.66 -7,743.32 8,857.56 5,957,904.78 357,911.70 0.67 10,995.32 MWD+IFR-AK-CAZ-SC(4) 14,953.92 84.12 148.34 7,609.05 7,538.25 -7,821.85 8,905.94 5,957,825.30 357,958.49 0.14 11,087.36 MWD+IFR-AK-CAZ-SC(4) 15,048.67 84.41 147.89 7,618.52 7,547.72 -7,901.90 8,955.74 5,957,744.28 358,006.67 0.56 11,181.42 MWD+IFR-AK-CAZ-SC(4) 15,142.04 86.13 147.66 7,626.22 7,555.42 -7,980.61 9,005.36 5,957,664.59 358,054.69 1.86 11,274.22 MWD+IFR-AK-CAZ-SC(4) 15,197.97 86.07 147.95 7,630.02 7,559.22 -8,027.83 9,035.09 5,957,616.78 358,083.47 0.53 11,329.87 MWD+IFR-AK-CAZ-SC(4) 15,251.01 86.89 148.21 7,633.28 7,562.48 -8,072.77 9,063.08 5,957,571.30 358,110.55 1.63 11,382.69 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 6 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope ND Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7-5/8"x 9-7/8"by 11" 15,292.25 87.53 148.42 7,635.29 7,564.49 -8,107.82 9,084.71 5,957,535.82 358,131.47 1.63 11,423.79 MWD+IFR-AK-CAZ-SC(5) 15,310.37 87.96 148.82 7,636.00 7,565.20 -8,123.28 9,094.14 5,957,520.18 358,140.59 3.24 11,441.87 MVVD+IFR-AK-CAZ-SC(5) 15,405.61 90.02 149.98 7,637.68 7,566.88 -8,205.24 9,142.61 5,957,437.27 358,187.40 2.48 11,536.99 MWD+IFR-AK-CAZ-SC(5) 15,501.26 89.31 148.89 7,638.24 7,567.44 -8,287.59 9,191.24 5,957,353.96 358,234.37 1.36 11,632.54 MWD+IFR-AK-CAZ-SC(5) 15,596.83 89.53 149.45 7,639.20 7,568.40 -8,369.65 9,240.22 5,957,270.94 358,281.68 0.63 11,727.99 MWD+IFR-AK-CAZ-SC(5) 15,691.63 89.39 150.70 7,640.10 7,569.30 -8,451.81 9,287.51 5,957,187.85 358,327.31 1.33 11,822.73 MWD+IFR-AK-CAZ-SC(5) 15,787.06 89.50 149.22 7,641.02 7,570.22 -8,534.41 9,335.28 5,957,104.31 358,373.41 1.56 11,918.09 MWD+IFR-AK-CAZ-SC(5) 15,882.48 89.28 148.90 7,642.04 7,571.24 -8,616.25 9,384.34 5,957,021.51 358,420.81 0.41 12,013.38 MWD+IFR-AK-CAZ-SC(5) 15,977.32 89.47 149.22 7,643.07 7,572.27 -8,697.59 9,433.09 5,956,939.21 358,467.92 0.39 12,108.09 MWD+IFR-AK-CAZ-SC(5) 16,072.60 89.36 147.08 7,644.05 7,573.25 -8,778.52 9,483.37 5,956,857.30 358,516.55 2.25 12,203.14 MWD+IFR-AK-CAZ-SC(5) 16,167.92 89.36 147.59 7,645.11 7,574.31 -8,858.75 9,534.81 5,956,776.05 358,566.37 0.54 12,298.14 MWD+IFR-AK-CAZ-SC(5) 16,263.96 89.53 147.68 7,646.04 7,575.24 -8,939.87 9,586.22 5,956,693.93 358,616.13 0.20 12,393.90 MWD+IFR-AK-CAZ-SC(5) 16,358.46 89.81 148.90 7,646.59 7,575.79 -9,020.26 9,635.89 5,956,612.56 358,664.18 1.32 12,488.19 MWD+IFR-AK-CAZ-SC(5) 16,454.76 89.84 150.14 7,646.88 7,576.08 -9,103.25 9,684.73 5,956,528.61 358,711.34 1.29 12,584.40 MWD+IFR-AK-CAZ-SC(5) 16,549.18 90.15 149.70 7,646.89 7,576.09 -9,184.96 9,732.06 5,956,445.98 358,757.01 0.57 12,678.76 MWD+IFR-AK-CAZ-SC(5) 16,644.62 90.35 151.03 7,646.47 7,575.67 -9,267.91 9,779.25 5,956,362.10 358,802.52 1.41 12,774.16 MWD+IFR-AK-CAZ-SC(5) 16,739.56 90.46 150.72 7,645.80 7,575.00 -9,350.84 9,825.46 5,956,278.26 358,847.05 0.35 12,869.08 MWD+IFR-AK-CAZ-SC(5) 16,835.34 90.19 152.06 7,645.26 7,574.46 -9,434.92 9,871.32 5,956,193.29 358,891.21 1.43 12,964.85 MWD+IFR-AK-CAZ-SC(5) 16,929.99 89.35 154.61 7,645.64 7,574.84 -9,519.50 9,913.79 5,956,107.88 358,931.98 2.84 13,059.46 MWD+IFR-AK-CAZ-SC(5) 17,025.88 89.30 155.47 7,646.77 7,575.97 -9,606.43 9,954.25 5,956,020.16 358,970.68 0.90 13,155.21 MVVD+IFR-AK-CAZ-SC(5) 17,121.16 88.72 152.90 7,648.41 7,577.61 -9,692.18 9,995.73 5,955,933.60 359,010.43 2.76 13,250.40 MWD+IFR-AK-CAZ-SC(5) 17,217.20 87.05 152.17 7,651.96 7,581.16 -9,777.33 10,040.00 5,955,847.58 359,052.97 1.90 13,346.36 MWD+IFR-AK-CAZ-SC(5) 17,312.13 85.70 152.37 7,657.96 7,587.16 -9,861.19 10,084.08 5,955,762.87 359,095.35 1.44 13,441.10 MWD+IFR-AK-CAZ-SC(5) 17,407.49 85.86 151.83 7,664.98 7,594.18 -9,945.24 10,128.58 5,955,677.95 359,138.16 0.59 13,536.20 MWD+IFR-AK-CAZ-SC(5) 17,502.89 85.85 150.69 7,671.87 7,601.07 -10,028.66 10,174.33 5,955,593.62 359,182.22 1.19 13,631.34 MWD+IFR-AK-CAZ-SC(5) 17,596.52 88.67 150.46 7,676.35 7,605.55 -10,110.11 10,220.27 5,955,511.27 359,226.51 3.02 13,724.83 MWD+IFR-AK-CAZ-SC(5) 17,691.34 89.61 149.46 7,677.77 7,606.97 -10,192.19 10,267.73 5,955,428.27 359,272.31 1.45 13,819.57 MVVD+IFR-AK-CAZ-SC(5) 17,787.19 89.57 148.51 7,678.46 7,607.66 -10,274.33 10,317.12 5,955,345.16 359,320.03 0.99 13,915.29 MWD+IFR-AK-CAZ-SC(5) 17,881.86 89.39 147.68 7,679.32 7,608.52 -10,354.69 10,367.15 5,955,263.81 359,368.44 0.90 14,009.73 MWD+IFR-AK-CAZ-SC(5) 17,977.44 89.16 149.07 7,680.53 7,609.73 -10,436.07 10,417.26 5,955,181.45 359,416.90 1.47 14,105.11 MWD+IFR-AK-CAZ-SC(5) 18,073.08 88.59 150.28 7,682.40 7,611.60 -10,518.61 10,465.54 5,955,097.97 359,463.51 1.40 14,200.65 MWD+IFR-AK-CAZ-SC(5) 18,168.71 88.64 151.09 7,684.71 7,613.91 -10,601.97 10,512.35 5,955,013.69 359,508.63 0.85 14,296.23 MWD+IFR-AK-CAZ-SC(5) 18,263.72 88.60 150.34 7,687.00 7,616.20 -10,684.81 10,558.81 5,954,929.94 359,553.42 0.79 14,391.19 MWD+IFR-AK-CAZ-SC(5) 18,359.06 88.60 150.72 7,689.33 7,618.53 -10,767.79 10,605.70 5,954,846.04 359,598.63 0.40 14,486.47 MWD+IFR-AK-CAZ-SC(5) 18,453.76 89.19 151.40 7,691.16 7,620.36 -10,850.65 10,651.52 5,954,762.29 359,642.77 0.95 14,581.14 MWD+IFR-AK-CAZ-SC(5) 18,549.17 89.81 150.79 7,691.99 7,621.19 -10,934.17 10,697.63 5,954,677.86 359,687.19 0.91 14,676.53 MWD+IFR-AK-CAZ-SC(5) 18,644.58 89.77 150.83 7,692.34 7,621.54 -11,017.46 10,744.16 5,954,593.66 359,732.04 0.06 14,771.92 MWD+IFR-AK-CAZ-SC(5) 18,739.51 89.73 150.42 7,692.76 7,621.96 -11,100.18 10,790.73 5,954,510.02 359,776.93 0.43 14,866.82 MWD+IFR-AK-CAZ-SC(5) 18,834.48 89.73 150.20 7,693.20 7,622.40 -11,182.68 10,837.77 5,954,426.60 359,822.30 0.23 14,961.75 M1MD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 7 COMPASS 5000.1 Build 74 • SLB S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope ND Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 18,929.83 90.22 150.03 7,693.24 7,622.44 -11,265.35 10,885.27 5,954,343.00 359,868.13 0.54 15,057.04 MWD+IFR-AK-CAZ-SC(5) 19,025.16 90.33 150.01 7,692.79 7,621.99 -11,347.93 10,932.91 5,954,259.49 359,914.10 0.12 15,152.32 MWD+IFR-AK-CAZ-SC(5) 19,120.20 89.93 151.41 7,692.57 7,621.77 -11,430.82 10,979.41 5,954,175.69 359,958.92 1.53 15,247.33 MWD+IFR-AK-CAZ-SC(5) 19,214.31 90.04 152.14 7,692.60 7,621.80 -11,513.74 11,023.91 5,954,091.90 360,001.75 0.78 15,341.44 MWD+IFR-AK-CAZ-SC(5) 19,310.29 90.16 152.74 7,692.43 7,621.63 -11,598.82 11,068.32 5,954,005.95 360,044.43 0.64 15,437.42 MWD+IFR-AK-CAZ-SC(5) . 19,407.13 89.52 154.82 7,692.70 7,621.90 -11,685.69 11,111.10 5,953,918.24 360,085.46 2.25 15,534.20 MWD+IFR-AK-CAZ-SC(5) 19,501.32 89.81 154.78 7,693.25 7,622.45 -11,770.92 11,151.21 5,953,832.23 360,123.84 0.31 15,628.28 MWD+IFR-AK-CAZ-SC(5) 19,595.70 89.74 156.91 7,693.62 7,622.82 -11,857.03 11,189.83 5,953,745.37 360,160.72 2.26 15,722.44 MWD+IFR-AK-CAZ-SC(5) 19,691.17 89.82 153.91 7,693.99 7,623.19 -11,943.83 11,229.55 5,953,657.80 360,198.69 3.14 15,817.73 MWD+IFR-AK-CAZ-SC(5) 19,786.12 88.97 153.85 7,694.99 7,624.19 -12,029.08 11,271.35 5,953,571.73 360,238.76 0.90 15,912.62 MWD+IFR-AK-CAZ-SC(5) 19,881.65 89.19 153.85 7,696.52 7,625.72 -12,114.82 11,313.44 5,953,485.17 360,279.13 0.23 16,008.09 MWD+IFR-AK-CAZ-SC(5) 19,976.05 89.12 154.41 7,697.92 7,627.12 -12,199.75 11,354.63 5,953,399.44 360,318.60 0.60 16,102.41 MWD+IFR-AK-CAZ-SC(5) 20,071.07 89.09 155.35 7,699.40 7,628.60 -12,285.77 11,394.96 5,953,312.63 360,357.19 0.99 16,197.30 MWD+IFR-AK-CAZ-SC(5) 20,167.40 88.92 158.37 7,701.07 7,630.27 -12,374.33 11,432.81 5,953,223.34 360,393.25 3.14 16,293.26 MWD+IFR-AK-CAZ-SC(5) 20,261.02 89.12 154.78 7,702.67 7,631.87 -12,460.20 11,470.01 5,953,136.74 360,428.72 3.84 16,386.55 MWD+IFR-AK-CAZ-SC(5) 20,356.17 89.26 153.21 7,704.02 7,633.22 -12,545.71 11,511.73 5,953,050.42 360,468.70 1.66 16,481.63 MWD+IFR-AK-CAZ-SC(5) 20,451.20 89.26 154.33 7,705.25 7,634.45 -12,630.94 11,553.72 5,952,964.36 360,508.98 1.18 16,576.61 MWD+IFR-AK-CAZ-SC(5) 20,547.02 89.16 153.23 7,706.57 7,635.77 -12,716.90 11,596.05 5,952,877.58 360,549.57 1.15 16,672.37 MWD+IFR-AK-CAZ-SC(5) 20,641.85 88.94 154.09 7,708.14 7,637.34 -12,801.87 11,638.12 5,952,791.79 360,589.92 0.94 16,767.15 MWD+IFR-AK-CAZ-SC(5) 20,737.66 89.22 153.51 7,709.68 7,638.88 -12,887.82 11,680.42 5,952,705.01 360,630.48 0.67 16,862.90 MWD+IFR-AK-CAZ-SC(5) 20,833.68 89.19 152.67 7,711.01 7,640.21 -12,973.44 11,723.87 5,952,618.55 360,672.20 0.88 16,958.89 MWD+IFR-AK-CAZ-SC(5) 20,928.95 89.07 152.52 7,712.46 7,641.66 -13,058.00 11,767.72 5,952,533.12 360,714.34 0.20 17,054.14 MWD+IFR-AK-CAZ-SC(5) 21,023.98 89.71 151.49 7,713.47 7,642.67 -13,141.91 11,812.32 5,952,448.35 360,757.24 1.28 17,149.17 MWD+IFR-AK-CAZ-SC(5) 21,119.93 89.49 152.36 7,714.14 7,643.34 -13,226.57 11,857.48 5,952,362.81 360,800.68 0.94 17,245.11 MWD+IFR-AK-CAZ-SC(5) 21,215.55 89.95 151.84 7,714.61 7,643.81 -13,311.07 11,902.22 5,952,277.43 360,843.72 0.73 17,340.73 M1IVD+IFR-AK-CAZ-SC(5) 21,311.03 90.02 151.75 7,714.63 7,643.83 -13,395.21 11,947.34 5,952,192.40 360,887.14 0.12 17,436.21 MWD+IFR-AK-CAZ-SC(5) 21,405.70 89.60 151.20 7,714.95 7,644.15 -13,478.39 11,992.55 5,952,108.34 360,930.67 0.73 17,530.87 MVVD+IFR-AK-CAZ-SC(5) 21,500.90 89.32 151.15 7,715.84 7,645.04 -13,561.79 12,038.45 5,952,024.04 360,974.88 0.30 17,626.06 MWD+IFR-AK-CAZ-SC(5) 21,596.84 89.04 150.19 7,717.22 7,646.42 -13,645.42 12,085.44 5,951,939.49 361,020.17 1.04 17,721.96 MWD+IFR-AK-CAZ-SC(5) 21,692.60 89.19 150.68 7,718.70 7,647.90 -13,728.70 12,132.68 5,951,855.28 361,065.73 0.54 17,817.68 MWD+IFR-AK-CAZ-SC(5) 21,788.05 88.91 149.65 7,720.28 7,649.48 -13,811.49 12,180.16 5,951,771.56 361,111.54 1.12 17,913.06 MWD+IFR-AK-CAZ-SC(5) 21,883.98 88.99 152.03 7,722.04 7,651.24 -13,895.24 12,226.89 5,951,686.90 361,156.57 2.48 18,008.95 MWD+IFR-AK-CAZ-SC(5) 21,978.50 89.02 149.36 7,723.68 7,652.88 -13,977.65 12,273.15 5,951,603.58 361,201.16 2.82 18,103.42 MWD+IFR-AK-CAZ-SC(5) 22,073.22 88.95 150.24 7,725.36 7,654.56 -14,059.50 12,320.78 5,951,520.80 361,247.14 0.93 18,198.06 MWD+IFR-AK-CAZ-SC(5) 22,168.94 89.05 148.14 7,727.03 7,656.23 -14,141.69 12,369.80 5,951,437.64 361,294.49 2.20 18,293.64 MWD+IFR-AK-CAZ-SC(5) 22,264.29 89.33 146.88 7,728.37 7,657.57 -14,222.11 12,421.01 5,951,356.22 361,344.07 1.35 18,388.69 MWD+IFR-AK-CAZ-SC(5) 22,359.82 89.08 147.87 7,729.70 7,658.90 -14,302.56 12,472.51 5,951,274.76 361,393.94 1.07 18,483.90 MWD+IFR-AK-CAZ-SC(5) 22,453.96 89.12 150.03 7,731.18 7,660.38 -14,383.19 12,521.06 5,951,193.17 361,440.86 2.29 18,577.89 MWD+IFR-AK-CAZ-SC(5) 22,549.61 89.16 150.34 7,732.61 7,661.81 -14,466.17 12,568.61 5,951,109.26 361,486.73 0.33 18,673.48 MWD+IFR-AK-CAZ-SC(5) 22,645.17 88.26 149.56 7,734.77 7,663.97 -14,548.87 12,616.45 5,951,025.63 361,532.89 1.25 18,768.95 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 8 COMPASS 5000.1 Build 74 • SLB S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9©70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 22,739.93 87.49 149.30 7,738.28 7,667.48 -14,630.40 12,664.61 5,950,943 15 361,579.40 0.86 18,863 55 MVD+IFR-AK-CAZ-SC(5) 22,835.16 87.64 148.71 7,742.33 7,671.53 -14,711.96 12,713.60 5,950,860.63 361,626.75 0.64 18,958.56 MWD+IFR-AK-CAZ-SC(5) 22,930.94 87.88 151.06 7,746.07 7,675.27 -14,794.74 12,761.62 5,950,776.91 361,673.09 2.46 19,054.20 MWD+IFR-AK-CAZ-SC(5) 23,025.51 88.72 150.61 7,748.87 7,678.07 -14,877.28 12,807.69 5,950,693.46 361,717.48 1.01 19,148.70 MWD+IFR-AK-CAZ-SC(5) 23,120.96 88.43 152.85 7,751.25 7,680.45 -14,961.32 12,852.88 5,950,608.55 361,760.98 2.37 19,244.12 MVVD+IFR-AK-CAZ-SC(5) 23,216.14 88.43 153.99 7,753.86 7,683.06 -15,046.40 12,895.45 5,950,522.63 361,801.83 1.20 19,339.23 MWD+IFR-AK-CAZ-SC(5) 23,310.89 89.09 154.24 7,755.91 7,685.11 -15,131.63 12,936.80 5,950,436.60 361,841.46 0.74 19,433.89 MWD+IFR-AK-CAZ-SC(5) 23,407.12 89.46 154.96 7,757.12 7,686.32 -15,218.55 12,978.08 5,950,348.87 361,880.97 0.84 19,530.02 MWD+IFR-AK-CAZ-SC(5) 23,502.84 89.91 155.52 7,757.65 7,686.85 -15,305.46 13,018.16 5,950,261.17 361,919.31 0.75 19,625.58 MWD+IFR-AK-CAZ-SC(5) 23,597.69 89.98 155.37 7,757.74 7,686.94 -15,391.74 13,057.58 5,950,174.13 361,956.98 0.17 19,720.26 MWD+IFR-AK-CAZ-SC(5) 23,693.15 89.39 155.46 7,758.27 7,687.47 -15,478.54 13,097.30 5,950,086.55 361,994.94 0.63 19,815.55 MWD+IFR-AK-CAZ-SC(5) 23,788.38 89.08 155.17 7,759.54 7,688.74 -15,565.06 13,137.06 5,949,999.26 362,032.96 0.45 19,910.61 MWD+IFR-AK-CAZ-SC(5) 23,883.67 89.19 154.68 7,760.98 7,690.18 -15,651.36 13,177.44 5,949,912.17 362,071.59 0.53 20,005.77 MWD+IFR-AK-CAZ-SC(5) 23,976.81 89.19 155.34 7,762.29 7,691.49 -15,735.77 13,216.79 5,949,827.00 362,109.23 0.71 20,098.77 MWD+IFR-AK-CAZ-SC(5) 24,074.20 89.15 155.36 7,763.70 7,692.90 -15,824.28 13,257.40 5,949,737.70 362,148.06 0.05 20,195.98 MWD+IFR-AK-CAZ-SC(5) 24,169.10 89.04 155.93 7,765.20 7,694.40 -15,910.72 13,296.53 5,949,650.49 362,185.44 0.61 20,290.68 MWD+IFR-AK-CAZ-SC(5) 24,264.29 89.47 156.58 7,766.44 7,695.64 -15,997.84 13,334.86 5,949,562.62 362,222.01 0.82 20,385.59 MWD+IFR-AK-CAZ-SC(5) 24,358.48 89.21 155.51 7,767.53 7,696.73 -16,083.91 13,373.10 5,949,475.81 362,258.51 1.17 20,479.54 MWD+IFR-AK-CAZ-SC(5) 24,454.31 89.92 155.09 7,768.25 7,697.45 -16,170.97 13,413.14 5,949,387.97 362,296.79 0.86 20,575.21 MWD+IFR-AK-CAZ-SC(5) 24,549.57 89.84 153.82 7,768.45 7,697.65 -16,256.92 13,454.22 5,949,301.22 362,336.13 1.34 20,670.38 MWD+IFR-AK-CAZ-SC(5) 24,644.46 89.84 152.45 7,768.72 7,697.92 -16,341.57 13,497.10 5,949,215.74 362,377.30 1.44 20,765.25 MWD+IFR-AK-CAZ-SC(5) 24,739.64 89.71 152.69 7,769.09 7,698.29 -16,426.04 13,540.94 5,949,130.40 362,419.44 0.29 20,860.42 MWD+IFR-AK-CAZ-SC(5) 24,834.39 88.65 152.68 7,770.45 7,699.65 -16,510.22 13,584.42 5,949,045.38 362,461.21 1.12 20,955.16 MWD+IFR-AK-CAZ-SC(5) 24,929.67 89.42 151.44 7,772.05 7,701.25 -16,594.38 13,629.05 5,948,960.35 362,504.14 1.53 21,050.42 MWD+IFR-AK-CAZ-SC(5) 25,025.67 88.23 150.89 7,774.02 7,703.22 -16,678.46 13,675.34 5,948,875.36 362,548.73 1.37 21,146.39 MWD+IFR-AK-CAZ-SC(5) 25,120.44 89.69 150.80 7,775.74 7,704.94 -16,761.20 13,721.50 5,948,791.71 362,593.22 1.54 21,241.12 MWD+IFR-AK-CAZ-SC(5) 25,215.48 89.14 150.36 7,776.71 7,705.91 -16,843.98 13,768.18 5,948,708.02 362,638.22 0.74 21,336.12 MWD+IFR-AK-CAZ-SC(5) 25,311.27 89.23 149.12 7,778.07 7,707.27 -16,926.71 13,816.45 5,948,624.34 362,684.81 1.30 21,431.83 MWD+IFR-AK-CAZ-SC(5) 25,407.05 88.88 150.99 7,779.65 7,708.85 -17,009.69 13,864.25 5,948,540.43 362,730.94 1.99 21,527.54 MWD+IFR-AK-CAZ-SC(5) 25,502.47 88.88 150.35 7,781.52 7,710.72 -17,092.86 13,910.98 5,948,456.34 362,775.98 0.67 21,622.91 MWD+IFR-AK-CAZ-SC(5) 25,599.03 89.05 149.69 7,783.26 7,712.46 -17,176.49 13,959.22 5,948,371.77 362,822.53 0.71 21,719.40 MWD+IFR-AK-CAZ-SC(5) 25,693.88 89.51 151.11 7,784.46 7,713.66 -17,258.95 14,006.07 5,948,288.39 362,867.71 1.57 21,814.20 MWD+IFR-AK-CAZ-SC(5) 25,789.07 89.29 150.65 7,785.45 7,714.65 -17,342.11 14,052.39 5,948,204.33 362,912.35 0.54 21,909.37 MWD+IFR-AK-CAZ-SC(5) 25,883.07 89.33 151.58 7,786.58 7,715.78 -17,424.40 14,097.79 5,948,121.14 362,956.09 0.99 22,003.35 MVVD+IFR-AK-CAZ-SC(5) 25,977.58 89.15 151.55 7,787.84 7,717.04 -17,507.50 14,142.79 5,948,037.16 362,999.40 0.19 22,097.85 MWD+IFR-AK-CAZ-SC(5) 26,074.97 89.18 151.43 7,789.26 7,718.46 -17,593.08 14,189.27 5,947,950.68 363,044.15 0.13 22,195.22 MWD+IFR-AK-CAZ-SC(5) 26,169.53 89.71 149.84 7,790.17 7,719.37 -17,675.48 14,235.64 5,947,867.36 363,088.85 1.77 22,289.75 MWD+IFR-AK-CAZ-SC(5) 26,265.79 90.01 150.87 7,790.41 7,719.61 -17,759.14 14,283.25 5,947,782.77 363,134.77 1.11 22,385.97 MWD+IFR-AK-CAZ-SC(5) 26,360.86 89.94 151.82 7,790.45 7,719.65 -17,842.56 14,328.84 5,947,698.45 363,178.67 1.00 22,481.03 MWD+IFR-AK-CAZ-SC(5) 26,456.52 89.77 152.10 7,790.69 7,719.89 -17,926.99 14,373.81 5,947,613.14 363,221.93 0.34 22,576.69 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 9 COMPASS 5000.1 Build 74 • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N-S +Et-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/900') (ft) Survey Tool Name 26,551.60 89.47 151.68 7,791.32 7,720 52 18,010.86 14,418.60 5,947,528.40 363,265.03 0.54 22,671.77 MWD+IFR-AK-CAZ-SC(5) 26,646.29 88.39 150.05 7,793.09 7,722.29 -18,093.55 14,464.69 5,947,444.81 363,309.45 2.06 22,766.42 MWD+IFR-AK-CAZ-SC(5) 26,741.87 88.02 149.53 7,796.08 7,725.28 -18,176.11 14,512.76 5,947,361.31 363,355.85 0.67 22,861.88 MWD+1FR-AK-CAZ-SC(5) 26,836.93 87.95 149.95 7,799.43 7,728.63 -18,258.16 14,560.64 5,947,278.31 363,402.06 0.45 22,956.81 MWD+IFR-AK-CAZ-SC(5) 26,932.73 87.81 150.25 7,802.97 7,732.17 -18,341.15 14,608.36 5,947,194.39 363,448.10 0.35 23,052.49 MWD+IFR-AK-CAZ-SC(5) 26,983.52 87.85 150.06 7,804.89 7,734.09 -18,385.18 14,633.62 5,947,149.87 363,472.47 0.39 23,103.21 MWD+IFR-AK-CAZ-SC(5) 4 1/2"x 6-3/4" 27,027.60 87.89 149.89 7,806.53 7,735.73 -18,423.31 14,655.66 5,947,111.30 363,493.74 0.39 23,147.24 MWD+IFR-AK-CAZ-SC(5) 27,089.00 87.89 149.89 7,808.79 7,737.99 -18,476.39 14,686.44 5,947,057.62 363,523.45 0.00 23,208.55 PROJECTED to TD 1/31/2017 4:45:04PM Page 10 COMPASS 5000.1 Build 74 OF Tb S g*.e\1//77, THE STATE Alaska Oil and Gas •"�� „ O A LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Hanna Sylte Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Colville River Field,Alpine Oil Pool, CRU CD5-18 Permit to Drill Number: 216-111 Sundry Number: 317-025 Dear Ms. Sylte: 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 2:o day of January, 2017. RDDNIS 'E'3 - '3 1017 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 19 2017 APPLICATION FOR SUNDRY APPROVALS 01A6 &/7 20 AAC 25.280 AO 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 Exploratory ❑ Development ❑• 216-111 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20750-00-00 ° 7.If perforating: 1 NI 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.....0 /i 1 CRU CD5-18 ° Will planned perforations require a spacing exception? Yes ❑ No 2( 9.Property Designation(Lease Number): 10.Field/Pool(s): ASRC NPR4,ASRC NPR2,ASRC-AA092344 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): 27,089' " 7,809' • 26,983' « 7,805' 7,500 Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 115' 115' Surface 2,354' 10-3/4" 2,390' 2,187' Intermediate 15,215' 7-5/8" 15,251' 7,633' Production Liner 12,865' 4-1/2" 26,983' 7,805' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 3 1/2" L80 14,126' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Halliburton TNT Production Packer,no SSSV 13,517'MD and 14,061'MD no SSSV 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2 ` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/31/2017 OIL ❑., . 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 Hanna Sylte,907-265-6342 Email Hanna.Sylte@ConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer C \-r( \ /1°l I2-01T-- Signature Phone 907-265-6342 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 -7- 025- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 141F t l-Z�I`4. Other: t ` Post Initial Injection MIT Req'd? Yes ❑ No 1:9"" r]Spacing Exception Required? Yes ❑ NoSubsequent Form Required: /6—4(04- RBDMS LF ED - 3 2017 APPROVED BY Approved by: I-e7COMMISSIONER THE COMMISSION Date: I 2_,C, _/7 I/TL �Z(p/ Submit For'(m and Form 10-403 Rse 11/2015 0 �ATrpYe app*ca�ior�is valid for 12 months from the date of approval. Attachments in Duplicate ? 114111- �-( (V� NAL cow 1241/7 • 0 --N WNS PROD CD5-18 ConocoPhillips )Well Attributes Max Angle&MD TD .30ccra 4,1.1.1 Nast Sams .33.:33:X.. -311.:1 SZ:1110$ Ad ail,Otte] .4,_41.45 .5.CO 27,2,33 n -. .:.,rre+It 42STrr; Z.. 4...41.04. E.11 C.. K.4.01111 RV flidageeDSIa .3...., ,11..:1115B; Es,Se. 4,:tstc, _ast OA,:Ey rEnd OS33 iftsistEdil ' I73 6 :.... 3. Casing Strings ' - Con Cwalpti. Ce:01 IC;Irt, T..'TIM. Sal Cir OISE; US CIO::TVZI. &as.Ii.STS. Tz:Tr ras1 I ,.„ ... ...„,...., . ,7.„,_,CleIrs Dseulphsrt OC;Et It;S T3::513332 1st Sid ttilE, $S Os,:T-1;. 4.1a..47,;.,.Gr! 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A 55_5_4.4:'..2 I"2;(-,21'1..EJE15.2.--, Z 7.-E-- 2.153 • ill '4 2E5 7 7 324 3 12 SS 4 4 -is.-.-_,-'-.--*;-a 4.4'..4.:I-34 2335 a ,-:il 4' 7 3.25 E. 1123 -,,,, 'IF,'cc. :351,E2E .::3:31:37 St St •4'24 2 7 321E 1147 '1..s.:7zs 13,1,0_22 2355 I t S a a S • S 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 THE ALASKA OIL AND GAS CONSERVATION COMMISSION 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 CD5-18 Well ) under the Provisions ) of 20 MC 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 MC 25.283(1) CPAI prepared the attached Notice of Operations(Notice"). 4. On January 13, 2017, 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 13th day of January,2017. -164.0'41 Garrett B. Haa STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 13th day of January,2017,by Garrett B. Haag. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC N.. REBECCA SWENSEN ♦ 1-7 my CameBssion Ex.'res Au..27,2020.E • . P.O.BOX 100360 ConocoPhillips ANCHORAGE,ALASKA 99510-0360 Alaska,Inc. Garrett B.Haag,Staff Landman Land Department,ATO 1480 Phone (907)265-6297 Fax (907)263-4966 Ga rrett.B.Haag@cop.com January 13, 2017 VIA CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1)for CD5-18 Well ASRC NPRA-02,ASRC NPRA-03,ASRC AA092347,ASRC NPRA-04,ADL387208,ASRC AA092344, and ADL387209 Colville River Unit,Alaska CPAI Contract No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") 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 CD5-18 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 17,2017. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases, ASRC NPRA-04,ASRC AA092344, and ASRC NPRA-02 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 391' 2,765' T11N R4E 18 Umiat Heel 3,113' 4,342' T11N R4E 21 Umiat Bottomhole 3,040' 3,986' T11N R4E 34 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, CPA1 will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, Garrett B. Haag Staff Landman Attachments: Exhibits 1 &2 • • Exhibit 1 / I Alpine PA ASRC-NPR3 ' ASRC-NPR2 ADL387207 I Coy rADL387208 I AA092347 A C-NPR4 IADL380075 II Nanuq 1 cb .__-_. �. ; Kuparuk PA . Qannik PA s r ---- I ASRC-AA092344 1 ADL380077 - \. .., I t.-.-.I gg E j AS F,NPR2 DL387209 I _17. . 1 i t -----• ------- AA081817 j ;5--•---- _ AD1388905 • CD5-18 Frac Points $ - 1/2 Mile Frac Point Buffer n 112 Mile Well Track Buffer T11 NR4E R CD5-18 Open Interval T1 ONR4E CD5-18 Well Track _ _j Alpine PA ASRC-NPR4 [ j Nanuq Kuparuk PA N ConocoPhillips L___.! Qannik PAAk Alaska,Inc. ADNR Sections CD5-18 BLM Townships 0 0.2 0.4 0.6 0.8 1 Lease Plat _ CPAI Leases Miles Date:1/12/2017 D,^tinleni Pathticuriou:.net\ai.share,Mt1C1Lonotenn4tkine'Cev eWcment Eno. GtS EAP130 IFID\Ge lerh mto1CRU v+;ellstCD5.1WCCc 111 Fault anal,sm w(Warms wo,l(n d 1 • • Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator& Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226(Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): Anadarko E&P Onshore LLC P.O. Box 1330 Houston,TX 77251-1330 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 State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Chantal Walsh,Director Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuigsut,AK 99789-0187 Attention: Joe Nukapigak,President • • ,Rau ,%hti- /tab? A Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles i; • •!pine A.45.ASRC-NPR3 ' '(P ADL387207 t„.:1.‘• _ — 1.", - 1 /// ,...._,..,____ „.....,__ _ __.: .1 ._ t.,p, i ‘ N AA092347 r ,_C-NPR ADL 208 I �& i t — ,ADL380076 .. i I Nanuq 1 C'� ----- Kuparuk PA , Qannik PA 8 � i ,t., i , A, ,.._..1 1 „...._....„ ASRC-AAI\. 2344 AOL380077 I 1 ; i — — 1 illk. DW87209 • 345 b I ii NPR2 I..-- — I • CD5-18 Frac Points i --- 98806 - 1/2 Mile Frac Point Buffer ri 1/2 Mile Well Track Buffer T11 NR4E j CD5-18 Open Interval i CD5-18 Well Track T1 ON R4 E , Wells within Track Buffer L_____i Alpine PA ASRC-NPR4 i i-_ __.i Nanuq Kuparuk PA 'I'''.- N ConocoPhillips L.._.1 Qannik PA A Alaska,Inc. ADNR Sections CD5-18 BLM Townships 0 0.2 0.4 0.6 0.8 1 Lease Plat 11111 CPAI Leases Miles Date: 1/20/2017 S 0 Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles Le ASRC-NPR3 i Alpine PA LASRC-NPR2 ADL387207 .,--— 1 i i 1 , 1 , .. AA092347A ; SC-NPR4 ADL387208 - 17 I \ 1 \ 1 fritiq jADI-38"75 ruk PA L__Clannik PA [ S 76. ,\ I , , 1 P 19 \ I „! / ASRCAA092344 it V ADL380077 0 i 1.? . A \ 004.32 1 -- P / L— ADL387209 -- !I I I —— - i 1 .3, / 1 I AS -NPR2 —7 ! i • C05-l8Frac Points i ...? ADL388905 Wells within Frac Point Buffer IIM 1/2 Mile Frac Point Buffer/, 1 IIM 1/2 Mile Well Track B .:r 1 =` T11 NR4E CD5-18 Open Int:f al T1 ONR4E C05-18 Well T- Li Alpine PA ASRC-NPR4 1 i ! Nanuq uparuk PA N ConocoPhillips [ I Qa ik PA Alaska,Inc. ADNR Sections CD5-18 BLM Townships 0 0.2 0.4 06 0.8 1 Lease Plat ME CPAI Leases Miles Date: 1/12/2017 Dun'eni Path',,cor.c.c.f1,8,,,la.5., a1V,I4C,i votern,P ont,,,f-ba,•-wril EncrAto".',IS E6P136 ItiMG4c4=ect:mfa,CFcti,Netivit51:1.CDE is falai analyse..,,,,t,Wria,,..,Pe,,,,,,' • 5 // ? .,14,1,' Table 1: Wells within .5 miles Well Name API Drill Site Status Well Type CD4-321 501032053600 CD4 ACTIVE INJ CD5-11 501032072600 CD5 ACTIVE INJ CD5-01 5010320736 CD5 ACTIVE INJ CD5-02 5010320737 CD5 ACTIVE INJ CD5-03 501032071800 CD5 ACTIVE PROD CD5-04 501032071100 CD5 ACTIVE PROD CD5-05 501032071200 CD5 ACTIVE PROD CD5-06 5010320744 CD5 ACTIVE INJ CD5-06L1 501032074460 CD5 ACTIVE INJ CD5-07 5010320734 CD5 ACTIVE INJ CD5-08 5010320741 CD5 ACTIVE INJ CD5-09 501032072300 CD5 ACTIVE PROD CD5-10 5010320724 CD5 ACTIVE PROD CD5-21 5010320738 CD5 PA N/A CD5-99 5010320748 CD5 PA N/A CD5-99A 501032074801 CD5 ACTIVE PROD CD5-99AL1 501032074861 CD5 ACTIVE PROD CD5-313 501032071400 CD5 ACTIVE PROD CD5-313PB1 501032071470 CD5 PA N/A CD5-314 501032070700 CD5 SUSP N/A CD5-315 501032071600 CD5 ACTIVE INJ CD5-315PB1 501032071670 CD5 PA N/A ! i Table 1 : Wells within .5 miles Well Name API Drill Site Stat s Well Type CD4-321 501032053600 CD4 A IVE INJ CD5-11 501032072600 CD5 ACTIVE INJ • S 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." • S 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. I • . 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 & %" casing cement pump report on 12/4/2016 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 10ppg mud. Full returns were seen throughout the job. The plug bumped at 1,020 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 12/16/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,300 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 12/5/2016 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 1/18/2017 the 7-5/8" casing was pressure tested to 2,400 psi on rig. On 1/18/2017 the 3.5" tubing was pressure tested to 4,100 psi. The 3.5" tubing will be pressure tested to 5,740 psi prior to frac'ing. c� The 7-5/8" casing will be pressure tested to 3,850-psi prior to frac'ing. 2..q-00 (5 17 AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,400 Annulus pressure during frac 2,182 Annulus PRV setpoint during frac 2,282 • 7 5/8" Annulus pressure test 2,400 3 1/2" Tubing pressure Test 5,740 Nitrogen PRV 8,740 Highest pump trip 8,540 • • 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 • Minimum pressure rating on all surface ar aeT Tattle 4:11 0.11 treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure 0 • IA parallel PRV set to 2,280 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV 01001 1:: rte;] • Tree saver used on all fracs rated for 15,000 psi. g 14;111.41 m •r H ', MI - 110: 10- 1V ca Y G 2 Kind U Pap-Off Tank Pap-0A Tank — Pump Truck ai ui o Fr Purip i1 ., .. I".�] Fra-r Li fp Frac Pump r..1 Frac4%unp Frac ip �` _; j_ f':). rr.,I Frac Purip • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR T`OMANDREL INSERTION) (MANDREL INSERTED} FRAC IRON CONNECTION /a/ D. a ,,, .. . 1 , REMOTE OPERATED ,:,:, MASTER VALVE ................ I .."wl�. .r .r� } ill 4 *f. � � *O i y` MANUAL OPERATED lir MASTER VALVE 10011.111111111111. 0110/101.Ma Ii'11a ` j • ( Stinger 1 MA 4 L 2 x VENT l 0 I.--VALVE y`* OPEN r i 11#t1t allthiRil zi•� .4 ,�, \I . 0, i d/ •• ; 't� FLOW TEE AND �/ . '' •%- VENT VALVE WELLHEAD 11111!w 11111 VALVES f/f r%/1/ OPENI;, 1,.k i r, WELLHEAD lCT'• VALVES ,,, •• zr CLOSED . '\ ,.' • irgb • ski.-#4&,-- id u QUAD PACKOFF flif s ASSEMBLY IN c,'. r e#. PLACE IN TUBING r il k TUBING i • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1/2 tubing and 1.75" down 3 %2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm i • Alpine Wellhead System ,�II 4 _,. , Ligriak it ' IP 11' ilk I T � '1'mli SWAreo+1.P.PTE . e) d 111111 - . .4;-Y .. I lia, IIIIIII tor mum ss, `�', x \\\ ,,.r= a_Iir r:.o Pwc xn..cca II \ .ter t ._�11 ; lJ�� l 7 ■ x w�. ,,, 1 li r . ..c.mn roar'- j :e� ., ;Th ' �� �F ,P'il. P.,.. -v a�� • .,a' : ' _:111.5.'% 1. JI I',==11Srt11'_ .a47x1 l< l.v I,W.ITi tlif 4 ee I R. i IM.44 PI4 ISI i3 III `'l K3i eaw .P 1,..Glt ,n _;114 i:..1'.Is_� , —.11&I •-— P�'� l A= 111 .„ uK�..v�xf- .- I el I li:c.j i . ' II' II' 'c�vnlw.Ti L.E .0.L pVrr fil ill 1. >Tal..� 111 �:I i 1- Lawn lis {1$�3.Z l�a1.Ior- li ,Fe Colll3 lr Vcoh t1 0 0 0 k55 r.+Cr Cfi.RCY._0,1 12.11 — I I'-6934 H 584,S 11 META wu pcR124+T S PEE .gig,_ ,� A x"� WITH se{a-11 METAL cum SEALS ^•"n , ter,.,l S 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 15,217' MD/7,561' TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 400' 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 12,786' MD/7,017' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases don section. The top of the Kingak interval ranges from -7590' TVDSS at the heel to -7760' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-18 wellbore). 0 0 ` on 8 ( To \j \ \/ 4.1▪ � a \ ka bo 4' 0Ea ", $ t = / 8 co 1771 01 ,- )k aZ� // ii 2 ] Q ! .� CU 1.1 a4E - COo ` ( CD $ Q E o | ; CO .. k 2 2 u E To • � � . V) E« - - Law §/ O• 12 — . C | LL §_ - - ;k § / a. To - - ; t A— /\ / / F-• £3 C k ( / CO )U K u S • 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: CD4-321: The 7" casing cement pump report on 10/21/2006 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 10.5 ppg mud. Full returns were seen throughout the job. Did not bump plug. Pressure was held on the cement head. CD5-11: The 7 & 5/8" casing cement report on 1/4/2016 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 10.9 ppg mud. Full returns were seen throughout the job. The plug did not bump, and the floats were checked and they held. • • 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 three faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-04. The first and third faults were interpreted from seismic data prior to drilling and confirmed with log data while drilling (fault throws of 29' and 9'). The second fault was not mapped with seismic data (fault throw of 3'). 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. The frac sleeves were placed 500' minimum away from faults to mitigate the risk of a fracture intersection. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage as soon as possible. Well Depth Depth Vertical Loss Name MD (ft) TVDSS(ft) Displacement (bbls/hr) CD5-18 17,030' 7,576' 29' None CD5-18 22,101' 7,655' 3' None CD5-18 22,470' 7,661' 9' None Table 3 —Drilled faults • 0 Plat 2: CD5-18 Fault Anal sis 1 A SRC-NPR3ADL387207 i_. /I 1 11 , i, i 1 __ AA092347 ADL387208 A -C-NPR4 ^- , ,, ,- i }L 1 NanuqADL380075 ,,, 1 Po , I 6' .. Kuparuk 61111116„ .76, i 4--,----1 . 1 A SRC-AA092344 ! ADL380077 i \ 1.... .. IIII i _CD4- I L_ _. ADL387209 1 i . _ 1, IP' , 1 • CD5-18 Frac Points A -. -NPR2 L ! Active Well Segments in Frac Point Buffer l ::14------ ADL388905 -Fault Segments in Frac Point Buffer = 1/2 Mile Frac Point Buffer MI 1/2 Mile Well Track Buffer T11 NR4E ........•.. .CD5-18 Open Interval T1 ONR4E - CD5-18 Well Track [ I Alpine PA A SRC-NPR4 LJ Nanuq Kuparuk PA N ConocoPhillips [ i Qannik PA l. Alaska,Inc. ADNR Sections CD5-18 BLM Townships 0 0.2 0.4 0.6 02 1 Fault Analysis 11111 CPA!Leases Miles Date: 1/12/2017 'Sonaynlk,:share,MN.::"LonaterrAlptnetrwelopm•rif EfrTskrc.CIS EA,Fir,INEAGORch irdaCRU,tx4sL'Of-IfiZD t8 NO anai.sk,.fmlakle3, • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-18 will be completed in 2017 as a multilateral horizontal producer in the Alpine A and C formations, with the frac planned for the A sand lateral. The well will be 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. The frac is only planned for the first half of the lateral due to reservoir properties. 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 20 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 system to ensure lines are clear and all components are functioning properly. 8. Pump the 310 bbl breakdown stage (25# Hybor G) according to the attached excel A HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure f+efitd21-690-psi.#o__ P .-375.90 psi as the tubing pressures up. Ensure sufficient volume is pumped to load „2,1(b 2tSi 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 attached HES schedule @ 25bpm with a maximum ii, 12,0'l expected treating pressure of 7,400 psi. • 8 stages, — 681,240 lbs of 20/40 Wanli proppant • Note due to time constraints the hydraulic fracturing treatment will 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. 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N p },Is= - 0 -OO (1) E u) o — coO CO L in O can) N o 73 N a) • .4= N CO 0)`. u > N ._, ui O (13 0) 5 73 C6 O E co -73 ‘,..-4-- CO .L7". :%-i a) .— L"Z 6 N C L w O = uw CL N s V) O L_ (IE a) )O a) O u) , ,0 co ri-1 in 0 - Q Li- -}-, = O = Q. +� I ir-1 CN (1) (ID =0)-0 1E— oc E 8 0 m "0 -0 8 7,:3 co 0 a) u . w = . u-, a, — O ca.-- (o -1::) c, s.... -c, , ) _c, w 2 0a. n = `D G) N O � r. r-, (.) O) _ CO2 0 ,___ tn .- oo Z � o p cCO - o -v' NJ p Oi. N Q .fit au) Li 2 .(7) 0 i= N , , O s= 'p N s- - r. t) .- .O C c a) O c inD O = •- -0 -0 • O u) Cn O O O r E . N -c E E w O I t . o C CU Cr) V) • • • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. 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(D U l a = t v +, rn t V. j .0 = c c o 0 v a y O.a cc 01 a tL. � c = o Q a o to c � • el. i > o i Z -I., V icx tri i o av a 0av N ` <tcv Q • • Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,January 26, 2017 10:15 AM To: Sylte, Hanna Subject: RE:CD5-18(PTD 216-111, Sundry 317-025))and CD5-99A(PTD 216-122, Sundry 316-645) Frac Sundry Update Hanna, We have reviewed the information provided on the CD4-321 mechanical integrity event as well as the information provided below pertaining to the CD5-99A and CD5-18 fracture stimulations.There will be no changes in the approved fracture stimulation sundry for CD5-99A(PTD 216-122,Sundry 316-645).The CD5-18(PTD 216-111,Sundry 317-025) fracture stimulation sundry is currently being processed. 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.LoeopCa 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.Loepp@alaska.gov From:Sylte, Hanna [mailto:Hanna.Sylte@conocophillips.com] Sent:Tuesday,January 24,2017 12:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:CD5-18(PTD 216-111)and CD5-99(PTD 216-122) Frac Sundry Update Victoria, This email is to clarify implications stemming from the CD4-321 mechanical integrity event,which we previously notified you of on 1/18, particularly for the stimulations of CD5-99(PTD#216-122)and CD5-18(PTD#216-111). • CD4-321 passed tubing and IA drawdown tests on 1/22 after setting a tubing plug on 1/20. • CD4-321 is scheduled for a combination MIT-TxIA on—1/24(and additional diagnostics as required)to confirm a downhole barrier. It failed a preliminary MIT-IA with crude freeze protect on 1/22/17. • On 1/14/17 the tubing and casing pack offs passed integrity tests, indicating a second tested barrier. • CD4-321 has a good primary cement job on the production casing based on the CBL,and a secondary cement job on the Qannik that went as planned. 1 ConocoPhillips has completed an ar1isis of the proposed hydraulic fractures o•5-99 and CD5-18 that shows these wells will have zonal isolation in the Alpine A Sand based on seismic,well and other subsurface information currently available and there is no reason to delay these stimulations based on the following: CD5-99 o CD5-99 is 1985'away from the CD4-321 Alpine A sand penetration(which has been P&A with cement), and 830'TVD below CD4-321 directly above where it crosses CD5-99 as indicated in the attached PowerPoint. o Frac modelling shows a 90'frac height growth and 520'frac half-length,so ConocoPhillips is confident the frac will be confined to the Alpine Sands and will not grow through the confining shales into CD4- 321. o The identified faults within a 1/2 mile radius of the wellbore do not extend up through the confining interval based on seismic,well and other subsurface information. CD5-18 o CD5-18 is 1150'away from the CD4-321 Alpine A sand penetration(which has been P&A with cement)as indicated in the attached PowerPoint. o Frac modelling shows a 90'frac height growth and 520'frac half-length,so ConocoPhillips is confident the frac will be confined to the Alpine Sands and will not grow through the confining shales into CD4-321. o The identified faults within a1/2 mile radius of the wellbore do not extend up through the confining interval based on seismic,well and other subsurface information. We wanted to be proactive in notifying the AOGCC of this change but would like to proceed with the stimulations that could start as early as 1/27, pending approvals. Please let me know if you have any questions or concerns. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office:(907)265-6342 Mobile:(713)449-2197 2 • • Loepp. Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Wednesday,January 25, 2017 11:01 AM To: Loepp,Victoria T(DOA) Subject: Fwd:Alpine injector CD4-321 (PTD#206-142,AIO 18C.002)failed MITIA Attachments: CD4-321 schematic.pdf;CD4-321 90-day TIO plot.docx Victoria, Below is the notification made to the AOGCC to report the failed MIT-IA on CD4-321. Please let me know if I can help with anything else. Thank you, Hanna Get Outlook for iOS From: NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> Sent:Wednesday,January 25,2017 10:43 AM Subject: FW:Alpine injector CD4-321(PTD#206-142,AIO 18C.002)failed MITIA To:Sylte, Hanna<hanna.syltePconocophillips.com> Hanna, Here is the email I sent to Chris Wallace last week to report the failed MIT on CD4-321. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: NSK Problem Well Supv Sent:Wednesday,January 18,2017 7:53 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:Alpine injector CD4-321(PTD#206-142,AIO 18C.002)failed MITIA Chris, Alpine injector CD4-321 (PTD#206-142,AIO 18C.002)failed an MITIA today during routine diagnostics prior to wellwork. The well will be SI and secured by slickline as soon as possible. Following the secure,we will do diagnostics to assess the well's condition. Based on the results of the diagnostics,we will develop and update you with a plan forward. Please let me know if you have any questions or disagree with this plan. Attached is a 90-day TIO plot and a schematic. 1 • • Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 • 41, Wallace, Chris D (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Tuesday,January 24, 2017 1:31 PM To: Wallace, Chris D (DOA) Subject: RE: Hydraulic Fracturing Sundry Application 317-025 CRU CD5-18 (PTD 2161110) Chris, We will pressure test the IA to 2400 psi prior to the frac, hold the IA pressure at 2182 psi during the frac and set the IA PRV to 2282 psi. We will pressure test the tubing to 5740 psi prior to the frac,with a maximum predicted treating pressure of 7400. Please let me know if you have any other questions or concerns about this sundry application. Thank you, Hanna From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent:Tuesday,January 24,2017 10:47 AM To:Sylte, Hanna <Hanna.Sylte@conocophillips.com> Subject: [EXTERNAL]Hydraulic Fracturing Sundry Application 317-025 CRU CD5-18(PTD 2161110) Hanna, We are reviewing the A-Sand stimulation sundry for CD5-18. Section 7 makes reference to tubing pressure testing of 5740 psi and IA pressure testing to 3850 psi,and states max IA during frac of 2182 psi. Section 8 Stimulation Surface rig up diagram states IA parallel PRV set to 2280 psi. Section 12 step 8 mentions the stage IA backpressure increasing from 2500 to 3500 psi. Section 12 step 10 makes reference to the maximum treating pressure as 7400 psi at 25 bpm. The 110%testing requirement of 20 AAC 25.283(b)casing IA does not seem to be met for these pressures? The 110%testing requirement of 20 AAC 25.283(c)(2)tubing/frac string does seem to be met for these pressures. Please confirm/identify the IA pressure for 20 AAC 25.283(a)(12)Step 8 of the frac procedure. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • . Bettis, Patricia K (DOA) From: Sylte, Hanna [Hanna.Sylte@conocophillips.com] Sent: Sunday, January 22, 2017 11:46 AM To: Bettis, Patricia K(DOA) Subject: RE: CRU CD5-18(PTD 216-111) Fracture Stimulation Sundry Application Attachments: CD5-18 Sundry Updated Section 2.pdf Patricia, I have attached an updated plat and well list including all of the wells within .5 mile of the wellbore trajectory.The plat on the original application only listed the wells within .5 miles of the frac ports. Please let me know if there is anything else that needs to be updated. Thank you, Hanna From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday,January 20, 2017 11:12 AM To:Sylte, Hanna <Hanna.Sylte@conocophillips.com> Subject: [EXTERNAL]CRU CD5-18(PTD 216-111) Fracture Stimulation Sundry Application Good morning Hanna, In reviewing Plat 1 Wells within 1/2 mile radius of CD5-18: it appears that CD5-06 and CD5-06L1 are within the%2 mile area review radius and yet are not showing up on the plat. Please submit an updated plat that shows the CD5-06 and CD5-06L1 wellbore trajectories and any other well that may lie within the AOR. 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 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday,January 20, 2017 11:12 AM To: Hanna.Sylte@conocophillips.com' Subject: CRU CD5-18 (PTD 216-111) Fracture Stimulation Sundry Application Good morning Hanna, In reviewing Plat 1 Wells within 1/2 mile radius of CD5-18: it appears that CD5-06 and CD5-06L1 are within the%z mile area review radius and yet are not showing up on the plat. Please submit an updated plat that shows the CD5-06 and CD5-06L1 wellbore trajectories and any other well that may lie within the AOR. 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 0 0 Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Wednesday,January 18, 2017 10:40 AM To: Loepp,Victoria T(DOA) Cc: Earhart,Will C Subject: CRU CD5-18L1 (PTD 216-112)IA Pressure Test Follow Up Flag: Follow up Flag Status: Flagged Victoria, On CRU CD5-18L1(PTD 216-112)we would like to amend the IA(3-1/2"tubing x 7-5/8"casing) pressure test to 2400psi. The approved PTD stated we would pressure test to 3500psi. We successfully conducted a charted pressure test of the 7-5/8"to 3500psi casing prior to drill out.Since then, however, we've run an ultra sonic log of the 7-5/8"casing that has identified some casing wear. Based on the worst case casing wear and using a safety factor of 1.15,we plan to limit the casing pressure test to 2400 psi. Please let me know if you approve of our path forward and if you would like to discuss further. Based upon current rig operations,we anticipate conducting the pressure test later this afternoon. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office:(907)265-6342 Mobile:(713)449-2197 1 e-- • • •10 v, - N H N ei Co wrwCI CC u r o > ,_ 7 N CV �-'m ovn {6 > m J Y o (0 Qet -rY O C e- N U N t > p O c0 a, O Y a L.. U a O_ C C a) }, C O Y .� .,-,› 6 W a-, 0 '6 a = C Q 4 0 .0 o al a 0 Q 0 J w Y a = 0 6- m J _ Y C OW 7 LL C ,0 U Q) G ZH 0 _6 r0 O Y N Zcd v > IS v Q - O C ¢¢I 0 a) -0 r0 U U O 0 C i v p L J J bn C U w W W vi v 'C Ll. LL. N aJ cu a.) 'O G i J J O_ .Q > a) C ._ C) .) Q Q u r`�'0 al w 4i O m . 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F- F-. • RECEIVED 2 1 6 1 1 1 27 95 5 FEB 0 7 2017 chiumberger AOGCC"' Transmittal#: 07FEB17-SPO1 Drilling & Measurements DATA LOGGED 2/'1/2011 MWD/LWD Log Product Delivery i1 K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-18 Date Dispatched: 7-Feb-17 Job#: 17AKA0002 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 Scope Resistivity 5'MD x x Scope Resistivity 5'ND x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x As-Built Survey 1 Contents on CD Nad83 x EOW CD 1 Contents on CD Data: DLIS/ASCII x Graphics: pdf x Survey:pdf/tut x Please sign and email a copy to: Please sign and email a copy to: Tom.OsterkampRconocophillips.com AlaskaPTSPrintCenter(aslb.com Attn: Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Received By: 21 61 11 27 95 5 RECEIVED FINAL FEB 0 7 2017 AOGCC NADConversion Western North Slope CD5 Alpine West Pad CD5-18 CD5-18 NAD 27 Definitive Survey Report 31 January, 2017 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-18 Well Position +N/-S 0.00 usft Northing: 5,965,823.83 usft Latitude: 70°18'49.398 N +E/-W 0.00 usft Easting: 349,212.08 usft Longitude: 151°13'19.556 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.90 usft Wellbore CD5-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BG G M 2016 11/21/2016 17.44 80.81 57,508 Design CD5-18 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.90 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.90 0.00 0.00 152.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 84.00 356.00 CD5-18 Svy1-SLB_GWD70(CD5-18) GYD-GC-SS Gyrodata gyro single shots 12/1/2016 12:59 385.12 2,324.62 CD5-18 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/1/2016 9:00: 2,358.13 2,358.13 CD5-18 Svy3-SLB_INC+Filler(CD5-18) INC+TREND Inclinometer+known azi trend 12/5/2016 9:36: 2,453.27 15,197.97 CD5-18 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/5/2016 9:40: 15,292.25 27,027.60 CD5-18 SvyS-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/19/2016 8:24 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) 0100') (ft) Survey Tool Name 36.90 0.00 0.00 36.90 -33.90 0.00 0.00 5,965,823.83 349,212.08 0.00 0.00 UNDEFINED 84.00 0.33 76.87 84.00 13.20 0.03 0.13 5,965,823.86 349,212.21 0.70 0.03 GYD-GC-SS(1) 115.00 0.56 29.85 115.00 44.20 0.18 0.29 5,965,824.01 349,212.38 1.33 -0.02 GYD-GC-SS(1) 115.90 0.55 30.98 115.90 45.10 0.19 0.30 5,965,824.01 349,212.38 1.67 -0 03 r 20"x 42" 171.00 0.68 127.23 171.00 100.20 0.22 0.70 5,965,824.04 349,212.78 1.67 0.13 GYD-G0-SS(1) 264.00 3.85 163.47 263.91 193.11 -3.11 2.02 5,965,820.68 349,214.04 3.58 3.70 GYD-GC-SS(1) 356.00 5.42 171.91 355.61 284.81 -10.37 3.51 5,965,813.39 349,215.38 1.86 10.81 GYD-GC-SS(1) 385.12 5.16 171.93 384.61 313.81 -13.03 3.89 5,965,810.73 349,215.71 0.89 13.33 MWD+IFR-AK-CAZ-SC(2) 477.47 5.47 175.37 476.56 405.76 -21.53 4.83 5,965,802.21 349,216.47 0.48 21.28 MWD+IFR-AK-CAZ-SC(2) 568.24 9.11 174.42 566.58 495.78 -33.00 5.88 5,965,790.72 349,217.29 4.01 31.89 MWD+IFR-AK-CAZ-SC(2) 1/31/2017 4:45:04PM Page 2 COMPASS 5000.1 Build 74 III • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 661.05 9.36 171.33 658.19 587.39 -47.77 7.73 5,965,775.92 349,218.85 0.60 45.81 MWD+IFR-AK-CAZ-SC(2) 751.80 10.03 170.95 747.64 676.84 -62.87 10.09 5,965,760.77 349,220.90 0.74 60.25 MWD+IFR-AK-CAZ-SC(2) 845.91 11.75 171.62 840.05 769.25 -80.45 12.77 5,965,743.15 349,223.23 1.83 77.02 MWD+IFR-AK-CAZ-SC(2) 940.18 12.80 166.75 932.17 861.37 -100.11 16.56 5,965,723.42 349,226.63 1.56 96.17 MWD+IFR-AK-CAZ-SC(2) 1,032.91 14.02 165.87 1,022.37 951.57 -121.00 21.66 5,965,702.43 349,231.30 1.33 117.01 MWD+IFR-AK-CAZ-SC(2) 1,126.89 15.56 165.25 1,113.23 1,042.43 -144.23 27.65 5,965,679.09 349,236.82 1.65 140.33 MWD+IFR-AK-CAZ-SC(2) 1,221.55 16.73 165.69 1,204.16 1,133.36 -169.71 34.25 5,965,653.48 349,242.91 1.24 165.92 MWD+IFR-AK-CAZ-SC(2) 1,315.85 20.07 164.25 1,293.63 1,222.83 -198.44 42.00 5,965,624.60 349,250.08 3.57 194.93 MWD+IFR-AK-CAZ-SC(2) 1,410.44 21.30 161.77 1,382.12 1,311.32 -230.38 51.78 5,965,592.47 349,259.22 1.60 227.72 MWD+IFR-AK-CAZ-SC(2) 1,504.77 25.42 157.37 1,468.71 1,397.91 -265.36 64.94 5,965,557.24 349,271.67 4.74 264.78 MWD+IFR-AK-CAZ-SC(2) 1,599.01 27.63 156.00 1,553.02 1,482.22 -304.00 81.61 5,965,518.28 349,287.56 2.43 306.73 MWD+IFR-AK-CAZ-SC(2) 1,692.54 28.46 155.81 1,635.57 1,564.77 -344.14 99.56 5,965,477.79 349,304.70 0.89 350.60 MWD+IFR-AK-CAZ-SC(2) 1,786.51 31.35 151.26 1,717.03 1,646.23 -386.01 120.50 5,965,435.51 349,324.79 3.91 397.40 MWD+IFR-AK-CAZ-SC(2) 1,878.21 34.95 149.01 1,793.79 1,722.99 -429.46 145.50 5,965,391.57 349,348.92 4.15 447.50 MWD+IFR-AK-CAZ-SC(2) 1,972.67 36.98 147.62 1,870.24 1,799.44 -476.65 174.65 5,965,343.80 349,377.11 2.32 502.85 MWD+IFR-AK-CAZ-SC(2) 2,066.79 38.40 145.66 1,944.73 1,873.93 -524.70 206.30 5,965,295.13 349,407.79 1.97 560.14 MWD+IFR-AK-CAZ-SC(2) 2,161.07 40.73 142.85 2,017.41 1,946.61 -573.41 241.40 5,965,245.74 349,441.90 3.12 619.62 MWD+IFR-AK-CAZ-SC(2) 2,253.23 41.56 137.78 2,086.83 2,016.03 -620.02 280.11 5,965,198.35 349,479.66 3.73 678.95 MWD+IFR-AK-CAZ-SC(2) 2,324.62 42.97 136.72 2,139.66 2,068.86 -655.27 312.71 5,965,162.46 349,511.54 2.21 725.38 MWD+IFR-AK-CAZ-SC(2) 2,358.13 43.68 136.32 2,164.03 2,093.23 -671.96 328.53 5,965,145.46 349,527.02 2.27 747.54 INC+TREND(3) 2,390.93 44.08 135.97 2,187.68 2,116.88 -688.35 344.28 5,965,128.75 349,542.44 1.43 769.41 ) 0010111111W10-3/4"x 13-1/2" atedI 2,453.27 44.85 135.33 2,232.17 2,161.37 -719.58 374.81 5,965,096.92 349,572.33 1.43 811.31 MWD+IFR-AK-CAZ-SC(4) 2,546.73 46.88 134.63 2,297.24 2,226.44 -766.98 422.26 5,965,048.58 349,618.82 2.24 875.44 MWD+IFR-AK-CAZ-SC(4) 2,641.67 50.17 131.46 2,360.12 2,289.32 -815.48 474.26 5,964,999.05 349,669.83 4.27 942.68 MWD+IFR-AK-CAZ-SC(4) 2,736.93 53.19 129.73 2,419.18 2,348.38 -864.09 531.01 5,964,949.32 349,725.59 3.48 1,012.24 MWD+IFR-AK-CAZ-SC(4) 2,830.92 55.73 127.99 2,473.82 2,403.02 -912.05 590.57 5,964,900.17 349,784.17 3.09 1,082.55 MWD+IFR-AK-CAZ-SC(4) 2,924.89 58.53 126.10 2,524.82 2,454.02 -959.58 653.56 5,964,851.40 349,846.19 3.43 1,154.09 MWD+IFR-AK-CAZ-SC(4) 3,020.04 61.73 124.85 2,572.20 2,501.40 -1,007.44 720.76 5,964,802.19 349,912.41 3.55 1,227.89 MWD+IFR-AK-CAZ-SC(4) 3,114.60 61.75 124.85 2,616.97 2,546.17 -1,055.04 789.11 5,964,753.24 349,979.78 0.02 1,302.00 MWD+IFR-AK-CAZ-SC(4) 3,209.57 61.67 125.50 2,661.98 2,591.18 -1,103.21 857.46 5,964,703.71 350,047.15 0.61 1,376.63 MWD+IFR-AK-CAZ-SC(4) 3,304.00 61.66 125.69 2,706.80 2,636.00 -1,151.59 925.05 5,964,653.98 350,113.75 0.18 1,451.08 MWD+IFR-AK-CAZ-SC(4) 3,397.53 62.14 125.78 2,750.85 2,680.05 -1,199.77 992.02 5,964,604.47 350,179.73 0.52 1,525.06 MWD+IFR-AK-CAZ-SC(4) 3,492.38 62.16 126.38 2,795.16 2,724.36 -1,249.16 1,059.80 5,964,553.73 350,246.50 0.56 1,600.49 MWD+IFR-AK-CAZ-SC(4) 3,586.20 62.06 127.05 2,839.05 2,768.25 -1,298.74 1,126.27 5,964,502.84 350,311.96 0.64 1,675.47 MWD+IFR-AK-CAZ-SC(4) 3,680.61 62.26 126.72 2,883.14 2,812.34 -1,348.84 1,193.04 5,964,451.40 350,377.71 0.37 1,751.06 MWD+IFR-AK-CAZ-SC(4) 3,775.49 62.22 127.74 2,927.33 2,856.53 -1,399.64 1,259.89 5,964,399.28 350,443.52 0.95 1,827.29 MWD+IFR-AK-CAZ-SC(4) 3,869.92 62.19 128.32 2,971.37 2,900.57 -1,451.10 1,325.69 5,964,346.51 350,508.26 0.54 1,903.62 MWD+IFR-AK-CAZ-SC(4) 3,964.06 62.23 127.97 3,015.26 2,944.46 -1,502.54 1,391.19 5,964,293.77 350,572.71 0.33 1,979.79 MWD+IFR-AK-CAZ-SC(4) 4,058.87 62.20 127.39 3,059.45 2,988.65 -1,553.81 1,457.57 5,964,241.18 350,638.05 0.54 2,056.22 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 3 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 4,152.20 61.92 127.74 3,103.18 3,032.38 -1,604.08 1,522.93 5,964,189.61 350,702.38 0.45 2,131.29 MWD+IFR-AK-CAZ-SC(4) 4,245.68 62.20 127.38 3,146.98 3,076.18 -1,654.42 1,588.39 5,964,137.97 350,766.81 0.45 2,206.47 MWD+IFR-AK-CAZ-SC(4) 4,340.73 62.59 127.00 3,191.03 3,120.23 -1,705.33 1,655.49 5,964,085.72 350,832.87 0.54 2,282.93 MWD+IFR-AK-CAZ-SC(4) 4,433.27 62.66 126.08 3,233.58 3,162.78 -1,754.26 1,721.52 5,964,035.49 350,897.89 0.89 2,357.12 MWD+IFR-AK-CAZ-SC(4) 4,527.69 62.51 124.82 3,277.06 3,206.26 -1,802.87 1,789.79 5,963,985.52 350,965.18 1.20 2,432.10 MWD+IFR-AK-CAZ-SC(4) 4,622.57 62.52 123.88 3,320.84 3,250.04 -1,850.36 1,859.28 5,963,936.64 351,033.69 0.88 2,506.66 MWD+IFR-AK-CAZ-SC(4) 4,716.91 62.66 122.99 3,364.28 3,293.48 -1,896.51 1,929.17 5,963,889.11 351,102.64 0.85 2,580.21 MWD+IFR-AK-CAZ-SC(4) 4,809.25 62.65 123.34 3,406.69 3,335.89 -1,941.38 1,997.83 5,963,842.87 351,170.38 0.34 2,652.06 MWD+IFR-AK-CAZ-SC(4) 4,903.70 62.71 123.35 3,450.04 3,379.24 -1,987.50 2,067.93 5,963,795.35 351,239.53 0.06 2,725.70 MWD+IFR-AK-CAZ-SC(4) 4,996.61 62.65 124.29 3,492.68 3,421.88 -2,033.45 2,136.51 5,963,748.04 351,307.17 0.90 2,798.46 MWD+IFR-AK-CAZ-SC(4) 5,090.38 62.64 125.01 3,535.77 3,464.97 -2,080.80 2,205.02 5,963,699.33 351,374.71 0.68 2,872.43 MWD+IFR-AK-CAZ-SC(4) 5,184.83 62.71 126.11 3,579.13 3,508.33 -2,129.60 2,273.28 5,963,649.17 351,441.97 1.04 2,947.57 MWD+IFR-AK-CAZ-SC(4) 5,279.37 62.77 126.26 3,622.43 3,551.63 -2,179.21 2,341.11 5,963,598.21 351,508.79 0.15 3,023.22 MWD+IFR-AK-CAZ-SC(4) 5,373.39 62.52 127.28 3,665.63 3,594.83 -2,229.20 2,408.01 5,963,546.89 351,574.66 1.00 3,098.76 MWD+IFR-AK-CAZ-SC(4) 5,466.99 62.68 127.56 3,708.71 3,637.91 -2,279.70 2,474.00 5,963,495.08 351,639.62 0.32 3,174.33 MWD+IFR-AK-CAZ-SC(4) 5,561.53 62.61 127.51 3,752.15 3,681.35 -2,330.85 2,540.59 5,963,442.60 351,705.16 0.09 3,250.76 MWD+IFR-AK-CAZ-SC(4) 5,656.00 62.58 127.23 3,795.63 3,724.83 -2,381.76 2,607.24 5,963,390.37 351,770.77 0.27 3,326.99 MWD+IFR-AK-CAZ-SC(4) 5,748.79 62.64 126.73 3,838.32 3,767.52 -2,431.32 2,673.06 5,963,339.51 351,835.58 0.48 3,401.65 MWD+IFR-AK-CAZ-SC(4) 5,843.84 62.78 125.93 3,881.90 3,811.10 -2,481.36 2,741.11 5,963,288.11 351,902.60 0.76 3,477.78 MWD+IFR-AK-CAZ-SC(4) 5,937.70 62.68 124.56 3,924.91 3,854.11 -2,529.50 2,809.24 5,963,238.61 351,969.75 1.30 3,552.28 MWD+IFR-AK-CAZ-SC(4) 6,031.84 62.71 124.40 3,968.09 3,897.29 -2,576.86 2,878.19 5,963,189.89 352,037.73 0.15 3,626.46 MWD+IFR-AK-CAZ-SC(4) 6,126.23 62.68 125.29 4,011.39 3,940.59 -2,624.78 2,947.03 5,963,140.60 352,105.59 0.84 3,701.09 MWD+IFR-AK-CAZ-SC(4) 6,220.52 62.75 125.14 4,054.62 3,983.82 -2,673.10 3,015.49 5,963,090.91 352,173.06 0.16 3,775.90 MWD+IFR-AK-CAZ-SC(4) 6,315.29 62.74 125.30 4,098.02 4,027.22 -2,721.69 3,084.32 5,963,040.96 352,240.89 0.15 3,851.11 MWD+IFR-AK-CAZ-SC(4) 6,410.03 62.68 125.64 4,141.45 4,070.65 -2,770.54 3,152.89 5,962,990.74 352,308.46 0.33 3,926.44 MWD+IFR-AK-CAZ-SC(4) 6,504.45 62.75 126.69 4,184.74 4,113.94 -2,820.06 3,220.63 5,962,939.87 352,375.19 0.99 4,001.96 MWD+IFR-AK-CAZ-SC(4) 6,597.88 62.69 127.68 4,227.56 4,156.76 -2,870.25 3,286.79 5,962,888.37 352,440.32 0.94 4,077.33 MWD+IFR-AK-CAZ-SC(4) 6,692.85 62.69 128.27 4,271.13 4,200.33 -2,922.17 3,353.31 5,962,835.13 352,505.78 0.55 4,154.41 MWD+IFR-AK-CAZ-SC(4) 6,786.89 62.65 127.74 4,314.31 4,243.51 -2,973.61 3,419.13 5,962,782.38 352,570.56 0.50 4,230.73 MWD+IFR-AK-CAZ-SC(4) 6,881.59 62.64 128.01 4,357.82 4,287.02 -3,025.25 3,485.53 5,962,729.42 352,635.89 0.25 4,307.49 MWD+IFR-AK-CAZ-SC(4) 6,975.69 62.65 128.04 4,401.06 4,330.26 -3,076.74 3,551.36 5,962,676.63 352,700.68 0.03 4,383.86 MWD+IFR-AK-CAZ-SC(4) 7,070.09 62.69 127.29 4,444.41 4,373.61 -3,127.98 3,617.75 5,962,624.07 352,766.02 0.71 4,460.27 MWD+IFR-AK-CAZ-SC(4) 7,165.37 62.72 126.10 4,488.10 4,417.30 -3,178.57 3,685.64 5,962,572.12 352,832.87 1.11 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,259.17 62.62 125.76 4,531.16 4,460.36 -3,227.47 3,753.11 5,962,521.89 352,899.35 0.34 4,611.67 MWD+IFR-AK-CAZ-SC(4) 7,354.03 62.19 125.10 4,575.11 4,504.31 -3,276.21 3,821.61 5,962,471.79 352,966.85 0.77 4,686.86 MWD+IFR-AK-CAZ-SC(4) 7,447.25 62.17 124.98 4,618.61 4,547.81 -3,323.54 3,889.12 5,962,423.11 353,033.38 0.12 4,760.34 MWD+IFR-AK-CAZ-SC(4) 7,541.72 62.23 124.33 4,662.67 4,591.87 -3,371.06 3,957.86 5,962,374.22 353,101.15 0.61 4,834.57 MWD+IFR-AK-CAZ-SC(4) 7,636.59 62.23 124.26 4,706.87 4,636.07 -3,418.36 4,027.21 5,962,325.55 353,169.53 0.07 4,908.89 MWD+IFR-AK-CAZ-SC(4) 7,730.82 62.22 125.34 4,750.78 4,679.98 -3,465.94 4,095.67 5,962,276.60 353,237.02 1.01 4,983.04 MWD+IFR-AK-CAZ-SC(4) 7,824.87 62.23 126.24 4,794.61 4,723.81 -3,514.60 4,163.17 5,962,226.60 353,303.52 0.85 5,057.70 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 4 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,920.41 62.17 126.71 4,839.17 4,768.37 -3,564.84 4,231.12 5,962,175.01 353,370.45 0.44 5,133.96 MWD+IFR-AK-CAZ-SC(4) 8,015.16 62.14 126.65 4,883.43 4,812.63 -3,614.89 4,298.31 5,962,123.63 353,436.62 0.06 5,209.69 MWD+IFR-AK-CAZ-SC(4) 8,108.34 62.17 126.43 4,926.95 4,856.15 -3,663.94 4,364.51 5,962,073.26 353,501.81 0.21 5,284.08 MWD+IFR-AK-CAZ-SC(4) 8,201.17 62.19 126.06 4,970.27 4,899.47 -3,712.48 4,430.72 5,962,023.40 353,567.03 0.35 5,358.03 MWD+IFR-AK-CAZ-SC(4) 8,295.29 62.16 125.59 5,014.21 4,943.41 -3,761.20 4,498.21 5,961,973.34 353,633.52 0.44 5,432.73 MWD+IFR-AK-CAZ-SC(4) 8,389.10 62.14 125.89 5,058.03 4,987.23 -3,809.65 4,565.54 5,961,923.55 353,699.86 0.28 5,507.11 MWD+IFR-AK-CAZ-SC(4) 8,483.45 62.13 125.36 5,102.13 5,031.33 -3,858.24 4,633.34 5,961,873.62 353,766.66 0.50 5,581.84 MWD+IFR-AK-CAZ-SC(4) 8,576.79 62.23 124.44 5,145.69 5,074.89 -3,905.47 4,701.04 5,961,825.04 353,833.40 0.88 5,655.33 MWD+IFR-AK-CAZ-SC(4) 8,671.18 62.28 124.61 5,189.63 5,118.83 -3,952.81 4,769.86 5,961,776.32 353,901.25 0.17 5,729.44 MWD+IFR-AK-CAZ-SC(4) 8,765.50 62.69 124.88 5,233.21 5,162.41 -4,000.49 4,838.60 5,961,727.28 353,969.01 0.50 5,803.81 MWD+IFR-AK-CAZ-SC(4) 8,859.72 62.73 125.83 5,276.41 5,205.61 -4,048.94 4,906.89 5,961,677.47 354,036.31 0.90 5,878.65 MWD+IFR-AK-CAZ-SC(4) 8,953.36 62.68 125.97 5,319.35 5,248.55 -4,097.73 4,974.30 5,961,627.34 354,102.72 0.14 5,953.38 MWD+IFR-AK-CAZ-SC(4) 9,047.60 62.63 126.61 5,362.64 5,291.84 -4,147.28 5,041.77 5,961,576.45 354,169.18 0.61 6,028.80 MWD+IFR-AK-CAZ-SC(4) 9,142.34 62.65 125.31 5,406.18 5,335.38 -4,196.69 5,109.87 5,961,525.69 354,236.27 1.22 6,104.39 MWD+IFR-AK-CAZ-SC(4) 9,236.31 62.64 124.96 5,449.36 5,378.56 -4,244.72 5,178.13 5,961,476.30 354,303.54 0.33 6,178.85 MWD+IFR-AK-CAZ-SC(4) 9,329.94 62.72 125.21 5,492.33 5,421.53 -4,292.53 5,246.20 5,961,427.13 354,370.63 0.25 6,253.02 MWD+IFR-AK-CAZ-SC(4) 9,423.56 62.62 124.36 5,535.31 5,464.51 -4,339.98 5,314.51 5,961,378.33 354,437.97 0.81 6,326.99 MWD+IFR-AK-CAZ-SC(4) 9,518.44 62.65 124.55 5,578.93 5,508.13 -4,387.65 5,383.99 5,961,329.27 354,506.47 0.18 6,401.70 MWD+IFR-AK-CAZ-SC(4) 9,613.17 62.72 124.33 5,622.40 5,551.60 -4,435.25 5,453.40 5,961,280.29 354,574.91 0.22 6,476.31 MWD+IFR-AK-CAZ-SC(4) 9,707.49 62.58 124.36 5,665.73 5,594.93 -4,482.52 5,522.57 5,961,231.65 354,643.11 0.15 6,550.52 MWD+IFR-AK-CAZ-SC(4) 9,801.90 62.72 124.09 5,709.10 5,638.30 -4,529.68 5,591.91 5,961,183.11 354,711.48 0.29 6,624.71 MWD+IFR-AK-CAZ-SC(4) 9,895.12 62.71 125.15 5,751.84 5,681.04 -4,576.75 5,660.08 5,961,134.68 354,778.70 1.01 6,698.28 MWD+IFR-AK-CAZ-SC(4) 9,989.24 62.85 125.63 5,794.89 5,724.09 -4,625.22 5,728.32 5,961,084.85 354,845.94 0.48 6,773.11 MWD+IFR-AK-CAZ-SC(4) 10,081.30 62.75 127.14 5,836.97 5,766.17 -4,673.79 5,794.23 5,961,034.97 354,910.86 1.46 6,846.94 MWD+IFR-AK-CAZ-SC(4) 10,175.34 62.79 127.04 5,880.00 5,809.20 -4,724.22 5,860.93 5,960,983.22 354,976.53 0.10 6,922.78 MWD+IFR-AK-CAZ-SC(4) 10,269.23 62.79 126.86 5,922.93 5,852.13 -4,774.41 5,927.66 5,960,931.70 355,042.23 0.17 6,998.43 MWD+IFR-AK-CAZ-SC(4) 10,363.59 62.59 127.69 5,966.23 5,895.43 -4,825.19 5,994.38 5,960,879.60 355,107.91 0.81 7,074.58 MWD+IFR-AK-CAZ-SC(4) 10,455.95 62.70 127.43 6,008.67 5,937.87 -4,875.20 6,059.41 5,960,828.30 355,171.92 0.28 7,149.26 MWD+IFR-AK-CAZ-SC(4) 10,550.12 62.65 126.87 6,051.89 5,981.09 -4,925.72 6,126.09 5,960,776.45 355,237.57 0.53 7,225.18 MWD+IFR-AK-CAZ-SC(4) 10,643.93 62.55 126.37 6,095.07 6,024.27 -4,975.40 6,192.93 5,960,725.44 355,303.40 0.49 7,300.42 MWD+IFR-AK-CAZ-SC(4) 10,738.33 62.62 126.27 6,138.53 6,067.73 -5,025.03 6,260.45 5,960,674.47 355,369.90 0.12 7,375.95 MWD+IFR-AK-CAZ-SC(4) 10,831.70 62.66 126.53 6,181.44 6,110.64 -5,074.24 6,327.20 5,960,623.93 355,435.64 0.25 7,450.73 MWD+IFR-AK-CAZ-SC(4) 10,924.78 62.70 125.50 6,224.16 6,153.36 -5,122.87 6,394.09 5,960,573.98 355,501.53 0.98 7,525.07 MWD+IFR-AK-CAZ-SC(4) 11,019.12 62.69 126.13 6,267.44 6,196.64 -5,171.92 6,462.07 5,960,523.57 355,568.51 0.59 7,600.29 MWD+IFR-AK-CAZ-SC(4) 11,113.38 62.15 126.32 6,311.08 6,240.28 -5,221.30 6,529.46 5,960,472.86 355,634.89 0.60 7,675.53 MWD+IFR-AK-CAZ-SC(4) 11,205.90 62.24 126.56 6,354.24 6,283.44 -5,269.91 6,595.30 5,960,422.94 355,699.74 0.25 7,749.36 MWD+IFR-AK-CAZ-SC(4) 11,300.07 62.13 127.17 6,398.18 6,327.38 -5,319.87 6,661.94 5,960,371.65 355,765.35 0.58 7,824.76 MWD+IFR-AK-CAZ-SC(4) 11,393.17 62.20 126.83 6,441.65 6,370.85 -5,369.42 6,727.69 5,960,320.80 355,830.09 0.33 7,899.37 MWD+IFR-AK-CAZ-SC(4) 11,486.75 62.17 126.57 6,485.32 6,414.52 -5,418.88 6,794.05 5,960,270.01 355,895.44 0.25 7,974.20 MWD+IFR-AK-CAZ-SC(4) 11,580.56 62.20 127.18 6,529.09 6,458.29 -5,468.67 6,860.42 5,960,218.91 355,960.79 0.58 8,049.32 MWD+IFR-AK-CAZ-SC(4) 1/31/2017 4:45:04PM Page 5 COMPASS 5000.I Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,674.78 62.27 127.64 6,572.98 6,502.18 -5,519.32 6,926.64 5,960,166.94 356,025.98 0.44 8,125.13 MWD+IFR-AK-CAZ-SC(4) 11,768.18 62.34 128.29 6,616.39 6,545.59 -5,570.20 6,991.84 5,960,114.77 356,090.14 0.62 8,200.66 MWD+1FR-AK-CAZ-SC(4) 11,862.91 62.14 129.15 6,660.51 6,589.71 -5,622.63 7,057.24 5,960,061.04 356,154.47 0.83 8,277.66 MWD+1FR-AK-CAZ-SC(4) 11,956.92 62.20 128.64 6,704.40 6,633.60 -5,674.83 7,121.95 5,960,007.55 356,218.11 0.48 8,354.13 MWD+1FR-AK-CAZ-SC(4) 12,049.21 62.18 128.64 6,747.46 6,676.66 -5,725.80 7,185.71 5,959,955.31 356,280.83 0.02 8,429.07 MWD+1FR-AK-CAZ-SC(4) 12,142.96 62.21 129.84 6,791.19 6,720.39 -5,778.26 7,249.93 5,959,901.58 356,343.98 1.13 8,505.54 MWD+IFR-AK-CAZ-SC(4) 12,236.77 62.58 130.38 6,834.66 6,763.86 -5,831.81 7,313.51 5,959,846.76 356,406.47 0.64 8,582.67 MWD+1FR-AK-CAZ-SC(4) 12,330.84 62.63 130.52 6,877.95 6,807.15 -5,886.00 7,377.07 5,959,791.32 356,468.92 0.14 8,660.35 MWD+IFR-AK-CAZ-SC(4) 12,424.49 62.66 132.26 6,920.98 6,850.18 -5,940.99 7,439.47 5,959,735.08 356,530.19 1.65 8,738.20 MWD+1FR-AK-CAZ-SC(4) 12,518.25 62.69 132.98 6,964.02 6,893.22 -5,997.40 7,500.76 5,959,677.47 356,590.34 0.68 8,816.78 MWD+IFR-AK-CAZ-SC(4) 12,611.31 62.62 133.38 7,006.77 6,935.97 -6,053.96 7,561.04 5,959,619.71 356,649.46 0.39 8,895.02 MWD+IFR-AK-CAZ-SC(4) 12,705.28 62.56 134.18 7,050.03 6,979.23 -6,111.68 7,621.27 5,959,560.80 356,708.52 0.76 8,974.26 MWD+IFR-AK-CAZ-SC(4) 12,798.86 62.41 133.92 7,093.26 7,022.46 -6,169.38 7,680.92 5,959,501.91 356,766.99 0.29 9,053.22 MWD+1FR-AK-CAZ-SC(4) • 12,892.88 62.38 134.29 7,136.83 7,066.03 -6,227.37 7,740.75 5,959,442.74 356,825.64 0.35 9,132.50 MWD+1FR-AK-CAZ-SC(4) 12,986.81 63.09 134.50 7,179.86 7,109.06 -6,285.78 7,800.40 5,959,383.14 356,884.11 0.78 9,212.09 MWD+1FR-AK-CAZ-SC(4) 13,080.34 63.18 134.12 7,222.12 7,151.32 -6,344.07 7,860.11 5,959,323.68 356,942.63 0.37 9,291.58 MWD+1FR-AK-CAZ-SC(4) 13,174.14 64.60 135.30 7,263.40 7,192.60 -6,403.32 7,919.96 5,959,263.23 357,001.27 1.89 9,371.99 MWD+1FR-AK-CAZ-SC(4) 13,268.65 65.84 136.73 7,303.02 7,232.22 -6,465.06 7,979.54 5,959,200.31 357,059.60 1.90 9,454.48 MWD+1FR-AK-CAZ-SC(4) 13,361.45 67.88 137.74 7,339.48 7,268.68 -6,527.71 8,037.48 5,959,136.52 357,116.26 2.42 9,536.99 MWD+1FR-AK-CAZ-SC(4) 13,455.04 70.12 138.25 7,373.02 7,302.22 -6,592.63 8,095.94 5,959,070.44 357,173.40 2.45 9,621.77 MWD+1FR-AK-CAZ-SC(4) 13,549.20 72.03 139.62 7,403.56 7,332.76 -6,659.79 8,154.44 5,959,002.13 357,230.54 2.45 9,708.52 MWD+1FR-AK-CAZ-SC(4) 13,643.10 73.37 141.03 7,431.48 7,360.68 -6,728.79 8,211.67 5,958,932.00 357,286.37 2.02 9,796.32 MWD+IFR-AK-CAZ-SC(4) 13,738.19 75.03 142.52 7,457.38 7,386.58 -6,800.67 8,268.28 5,958,859.00 357,341.52 2.31 9,886.36 MWD+1FR-AK-CAZ-SC(4) 13,830.52 76.88 143.97 7,479.78 7,408.98 -6,872.43 8,321.87 5,958,786.19 357,393.65 2.52 9,974.88 MWD+1FR-AK-CAZ-SC(4) 13,924.72 79.22 145.65 7,499.29 7,428.49 -6,947.74 8,374.97 5,958,709.83 357,445.22 3.04 10,066.30 MWD+IFR-AK-CAZ-SC(4) 14,018.68 81.68 146.65 7,514.88 7,444.08 -7,024.69 8,426.58 5,958,631.87 357,495.27 2.82 10,158.47 MWD+1FR-AK-CAZ-SC(4) 14,113.21 83.32 146.90 7,527.21 7,456.41 -7,103.09 8,477.93 5,958,552.46 357,545.03 1.75 10,251.80 MWD+IFR-AK-CAZ-SC(4) 14,204.97 84.50 149.24 7,536.95 7,466.15 -7,180.52 8,526.18 5,958,474.08 357,591.71 2.84 10,342.82 MWD+1FR-AK-CAZ-SC(4) 14,299.09 84.99 150.16 7,545.57 7,474.77 -7,261.44 8,573.46 5,958,392.23 357,637.36 1.10 10,436.47 MWD+IFR-AK-CAZ-SC(4) 14,393.31 85.21 150.93 7,553.62 7,482.82 -7,343.18 8,619.62 5,958,309.59 357,681.87 0.85 10,530.31 MWD+1FR-AK-CAZ-SC(4) 14,487.43 84.36 150.55 7,562.17 7,491.37 -7,424.95 8,665.44 5,958,226.92 357,726.03 0.99 10,624.02 MWD+1FR-AK-CAZ-SC(4) 14,580.27 84.56 149.74 7,571.14 7,500.34 -7,505.09 8,711.44 5,958,145.88 357,770.40 0.89 10,716.37 MWD+1FR-AK-CAZ-SC(4) 14,674.94 84.36 148.61 7,580.28 7,509.48 -7,586.01 8,759.72 5,958,064.01 357,817.05 1.21 10,810.49 MWD+1FR-AK-CAZ-SC(4) 14,767.23 84.00 147.75 7,589.63 7,518.83 -7,664.02 8,808.13 5,957,985.05 357,863.88 1.01 10,902.09 MWD+1FR-AK-CAZ-SC(4) 14,861.19 84.00 148.38 7,599.46 7,528.66 -7,743.32 8,857.56 5,957,904.78 357,911.70 0.67 10,995.32 MWD+1FR-AK-CAZ-SC(4) 14,953.92 84.12 148.34 7,609.05 7,538.25 -7,821.85 8,905.94 5,957,825.30 357,958.49 0.14 11,087.36 MWD+1FR-AK-CAZ-SC(4) 15,048.67 84.41 147.89 7,618.52 7,547.72 -7,901.90 8,955.74 5,957,744.28 358,006.67 0.56 11,181.42 MWD+1FR-AK-CAZ-SC(4) 15,142.04 86.13 147.66 7,626.22 7,555.42 -7,980.61 9,005.36 5,957,664.59 358,054.69 1.86 11,274.22 MWD+IFR-AK-CAZ-SC(4) 15,197.97 86.07 147.95 7,630.02 7,559.22 -8,027.83 9,035.09 5,957,616.78 358,083.47 0.53 11,329.87 MWD+1FR-AK-CAZ-SC(4) 15,251.01 86.89 148.21 7,633.28 7,562.48 -8,072.77 9,063.08 5,957,571.30 358,110.55 1.63 11,382.69 4011111111111010111 1/31/2017 4:45:04PM Page 6 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name L 7-5/8"x 9-718"by 11"__ 15,292.25 87.53 148.42 7,635.29 7,564.49 -8,107.82 9,084.71 5,957,535.82 358,131.47 1.63 11,423.79 MWD+IFR-AK-CAZ-SC(5) 15,310.37 87.96 148.82 7,636.00 7,565.20 -8,123.28 9,094.14 5,957,520.18 358,140.59 3.24 11,441.87 MWD+IFR-AK-CAZ-SC(5) 15,405.61 90.02 149.98 7,637.68 7,566.88 -8,205.24 9,142.61 5,957,437.27 358,187.40 2.48 11,536.99 MWD+IFR-AK-CAZ-SC(5) 15,501.26 89.31 148.89 7,638.24 7,567.44 -8,287.59 9,191.24 5,957,353.96 358,234.37 1.36 11,632.54 MWD+IFR-AK-CAZ-SC(5) 15,596.83 89.53 149.45 7,639.20 7,568.40 -8,369.65 9,240.22 5,957,270.94 358,281.68 0.63 11,727.99 MWD+IFR-AK-CAZ-SC(5) 15,691.63 89.39 150.70 7,640.10 7,569.30 -8,451.81 9,287.51 5,957,187.85 358,327.31 1.33 11,822.73 MWD+IFR-AK-CAZ-SC(5) 15,787.06 89.50 149.22 7,641.02 7,570.22 -8,534.41 9,335.28 5,957,104.31 358,373.41 1.56 11,918.09 MWD+IFR-AK-CAZ-SC(5) 15,882.48 89.28 148.90 7,642.04 7,571.24 -8,616.25 9,384.34 5,957,021.51 358,420.81 0.41 12,013.38 MWD+IFR-AK-CAZ-SC(5) 15,977.32 89.47 149.22 7,643.07 7,572.27 -8,697.59 9,433.09 5,956,939.21 358,467.92 0.39 12,108.09 MWD+IFR-AK-CAZ-SC(5) 16,072.60 89.36 147.08 7,644.05 7,573.25 -8,778.52 9,483.37 5,956,857.30 358,516.55 2.25 12,203.14 MWD+IFR-AK-CAZ-SC(5) 16,167.92 89.36 147.59 7,645.11 7,574.31 -8,858.75 9,534.81 5,956,776.05 358,566.37 0.54 12,298.14 MWD+IFR-AK-CAZ-SC(5) 16,263.96 89.53 147.68 7,646.04 7,575.24 -8,939.87 9,586.22 5,956,693.93 358,616.13 0.20 12,393.90 MWD+IFR-AK-CAZ-SC(5) 16,358.46 89.81 148.90 7,646.59 7,575.79 -9,020.26 9,635.89 5,956,612.56 358,664.18 1.32 12,488.19 MWD+IFR-AK-CAZ-SC(5) 16,454.76 89.84 150.14 7,646.88 7,576.08 -9,103.25 9,684.73 5,956,528.61 358,711.34 1.29 12,584.40 MWD+IFR-AK-CAZ-SC(5) 16,549.18 90.15 149.70 7,646.89 7,576.09 -9,184.96 9,732.06 5,956,445.98 358,757.01 0.57 12,678.76 MWD+IFR-AK-CAZ-SC(5) 16,644.62 90.35 151.03 7,646.47 7,575.67 -9,267.91 9,779.25 5,956,362.10 358,802.52 1.41 12,774.16 MWD+IFR-AK-CAZ-SC(5) 16,739.56 90.46 150.72 7,645.80 7,575.00 -9,350.84 9,825.46 5,956,278.26 358,847.05 0.35 12,869.08 MWD+IFR-AK-CAZ-SC(5) 16,835.34 90.19 152.06 7,645.26 7,574.46 -9,434.92 9,871.32 5,956,193.29 358,891.21 1.43 12,964.85 MWD+IFR-AK-CAZ-SC(5) 16,929.99 89.35 154.61 7,645.64 7,574.84 -9,519.50 9,913.79 5,956,107.88 358,931.98 2.84 13,059.46 MWD+IFR-AK-CAZ-SC(5) 17,025.88 89.30 155.47 7,646.77 7,575.97 -9,606.43 9,954.25 5,956,020.16 358,970.68 0.90 13,155.21 MWD+IFR-AK-CAZ-SC(5) 17,121.16 88.72 152.90 7,648.41 7,577.61 -9,692.18 9,995.73 5,955,933.60 359,010.43 2.76 13,250.40 MWD+IFR-AK-CAZ-SC(5) 17,217.20 87.05 152.17 7,651.96 7,581.16 -9,777.33 10,040.00 5,955,847.58 359,052.97 1.90 13,346.36 MWD+IFR-AK-CAZ-SC(5) 17,312.13 85.70 152.37 7,657.96 7,587.16 -9,861.19 10,084.08 5,955,762.87 359,095.35 1.44 13,441.10 MWD+IFR-AK-CAZ-SC(5) 17,407.49 85.86 151.83 7,664.98 7,594.18 -9,945.24 10,128.58 5,955,677.95 359,138.16 0.59 13,536.20 MWD+IFR-AK-CAZ-SC(5) 17,502.89 85.85 150.69 7,671.87 7,601.07 -10,028.66 10,174.33 5,955,593.62 359,182.22 1.19 13,631.34 MWD+IFR-AK-CAZ-SC(5) 17,596.52 88.67 150.46 7,676.35 7,605.55 -10,110.11 10,220.27 5,955,511.27 359,226.51 3.02 13,724.83 MWD+IFR-AK-CAZ-SC(5) 17,691.34 89.61 149.46 7,677.77 7,606.97 -10,192.19 10,267.73 5,955,428.27 359,272.31 1.45 13,819.57 MWD+IFR-AK-CAZ-SC(5) 17,787.19 89.57 148.51 7,678.46 7,607.66 -10,274.33 10,317.12 5,955,345.16 359,320.03 0.99 13,915.29 MWD+IFR-AK-CAZ-SC(5) 17,881.86 89.39 147.68 7,679.32 7,608.52 -10,354.69 10,367.15 5,955,263.81 359,368.44 0.90 14,009.73 MWD+IFR-AK-CAZ-SC(5) 17,977.44 89.16 149.07 7,680.53 7,609.73 -10,436.07 10,417.26 5,955,181.45 359,416.90 1.47 14,105.11 MWD+IFR-AK-CAZ-SC(5) 18,073.08 88.59 150.28 7,682.40 7,611.60 -10,518.61 10,465.54 5,955,097.97 359,463.51 1.40 14,200.65 MWD+IFR-AK-CAZ-SC(5) 18,168.71 88.64 151.09 7,684.71 7,613.91 -10,601.97 10,512.35 5,955,013.69 359,508.63 0.85 14,296.23 MWD+IFR-AK-CAZ-SC(5) 18,263.72 88.60 150.34 7,687.00 7,616.20 -10,684.81 10,558.81 5,954,929.94 359,553.42 0.79 14,391.19 MWD+IFR-AK-CAZ-SC(5) 18,359.06 88.60 150.72 7,689.33 7,618.53 -10,767.79 10,605.70 5,954,846.04 359,598.63 0.40 14,486.47 MWD+IFR-AK-CAZ-SC(5) 18,453.76 89.19 151.40 7,691.16 7,620.36 -10,850.65 10,651.52 5,954,762.29 359,642.77 0.95 14,581.14 MWD+IFR-AK-CAZ-SC(5) 18,549.17 89.81 150.79 7,691.99 7,621.19 -10,934.17 10,697.63 5,954,677.86 359,687.19 0.91 14,676.53 MWD+IFR-AK-CAZ-SC(5) 18,644.58 89.77 150.83 7,692.34 7,621.54 -11,017.46 10,744.16 5,954,593.66 359,732.04 0.06 14,771.92 MWD+IFR-AK-CAZ-SC(5) 18,739.51 89.73 150.42 7,692.76 7,621.96 -11,100.18 10,790.73 5,954,510.02 359,776.93 0.43 14,866.82 MWD+IFR-AK-CAZ-SC(5) 18,834.48 89.73 150.20 7,693.20 7,622.40 -11,182.68 10,837.77 5,954,426.60 359,822.30 0.23 14,961.75 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 7 COMPASS 50004 Build 74 i 0 SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.8ousft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,929.83 90.22 150.03 7,693.24 7,622.44 -11,265.35 10,885.27 5,954,343.00 359,868.13 0.54 15,057.04 MWD+IFR-AK-CAZ-SC(5) 19,025.16 90.33 150.01 7,692.79 7,621.99 -11,347.93 10,932.91 5,954,259.49 359,914.10 0.12 15,152.32 MWD+IFR-AK-CAZ-SC(5) 19,120.20 89.93 151.41 7,692.57 7,621.77 -11,430.82 10,979.41 5,954,175.69 359,958.92 1.53 15,247.33 MWD+IFR-AK-CAZ-SC(5) 19,214.31 90.04 152.14 7,692.60 7,621.80 -11,513.74 11,023.91 5,954,091.90 360,001.75 0.78 15,341.44 MWD+IFR-AK-CAZ-SC(5) 19,310.29 90.16 152.74 7,692.43 7,621.63 -11,598.82 11,068.32 5,954,005.95 360,044.43 0.64 15,437.42 MWD+IFR-AK-CAZ-SC(5) 19,407.13 89.52 154.82 7,692.70 7,621.90 -11,685.69 11,111.10 5,953,918.24 360,085.46 2.25 15,534.20 MWD+IFR-AK-CAZ-SC(5) 19,501.32 89.81 154.78 7,693.25 7,622.45 -11,770.92 11,151.21 5,953,832.23 360,123.84 0.31 15,628.28 MWD+IFR-AK-CAZ-SC(5) 19,595.70 89.74 156.91 7,693.62 7,622.82 -11,857.03 11,189.83 5,953,745.37 360,160.72 2.26 15,722.44 MWD+IFR-AK-CAZ-SC(5) 19,691.17 89.82 153.91 7,693.99 7,623.19 -11,943.83 11,229.55 5,953,657.80 360,198.69 3.14 15,817.73 MWD+IFR-AK-CAZ-SC(5) 19,786.12 88.97 153.85 7,694.99 7,624.19 -12,029.08 11,271.35 5,953,571.73 360,238.76 0.90 15,912.62 MWD+IFR-AK-CAZ-SC(5) 19,881.65 89.19 153.85 7,696.52 7,625.72 -12,114.82 11,313.44 5,953,485.17 360,279.13 0.23 16,008.09 MWD+IFR-AK-CAZ-SC(5) 19,976.05 89.12 154.41 7,697.92 7,627.12 -12,199.75 11,354.63 5,953,399.44 360,318.60 0.60 16,102.41 MWD+IFR-AK-CAZ-SC(5) 20,071.07 89.09 155.35 7,699.40 7,628.60 -12,285.77 11,394.96 5,953,312.63 360,357.19 0.99 16,197.30 MWD+IFR-AK-CAZ-SC(5) 20,167.40 88.92 158.37 7,701.07 7,630.27 -12,374.33 11,432.81 5,953,223.34 360,393.25 3.14 16,293.26 MWD+IFR-AK-CAZ-SC(5) 20,261.02 89.12 154.78 7,702.67 7,631.87 -12,460.20 11,470.01 5,953,136.74 360,428.72 3.84 16,386.55 MWD+IFR-AK-CAZ-SC(5) 20,356.17 89.26 153.21 7,704.02 7,633.22 -12,545.71 11,511.73 5,953,050.42 360,468.70 1.66 16,481.63 MWD+IFR-AK-CAZ-SC(5) 20,451.20 89.26 154.33 7,705.25 7,634.45 -12,630.94 11,553.72 5,952,964.36 360,508.98 1.18 16,576.61 MWD+IFR-AK-CAZ-SC(5) 20,547.02 89.16 153.23 7,706.57 7,635.77 -12,716.90 11,596.05 5,952,877.58 360,549.57 1.15 16,672.37 MWD+IFR-AK-CAZ-SC(5) 20,641.85 88.94 154.09 7,708.14 7,637.34 -12,801.87 11,638.12 5,952,791.79 360,589.92 0.94 16,767.15 MWD+IFR-AK-CAZ-SC(5) 20,737.66 89.22 153.51 7,709.68 7,638.88 -12,887.82 11,680.42 5,952,705.01 360,630.48 0.67 16,862.90 MWD+IFR-AK-CAZ-SC(5) 20,833.68 89.19 152.67 7,711.01 7,640.21 -12,973.44 11,723.87 5,952,618.55 360,672.20 0.88 16,958.89 MWD+IFR-AK-CAZ-SC(5) 20,928.95 89.07 152.52 7,712.46 7,641.66 -13,058.00 11,767.72 5,952,533.12 360,714.34 0.20 17,054.14 MWD+IFR-AK-CAZ-SC(5) 21,023.98 89.71 151.49 7,713.47 7,642.67 -13,141.91 11,812.32 5,952,448.35 360,757.24 1.28 17,149.17 MWD+IFR-AK-CAZ-SC(5) 21,119.93 89.49 152.36 7,714.14 7,643.34 -13,226.57 11,857.48 5,952,362.81 360,800.68 0.94 17,245.11 MWD+IFR-AK-CAZ-SC(5) 21,215.55 89.95 151.84 7,714.61 7,643.81 -13,311.07 11,902.22 5,952,277.43 360,843.72 0.73 17,340.73 MWD+IFR-AK-CAZ-SC(5) 21,311.03 90.02 151.75 7,714.63 7,643.83 -13,395.21 11,947.34 5,952,192.40 360,887.14 0.12 17,436.21 MWD+IFR-AK-CAZ-SC(5) 21,405.70 89.60 151.20 7,714.95 7,644.15 -13,478.39 11,992.55 5,952,108.34 360,930.67 0.73 17,530.87 MWD+IFR-AK-CAZ-SC(5) 21,500.90 89.32 151.15 7,715.84 7,645.04 -13,561.79 12,038.45 5,952,024.04 360,974.88 0.30 17,626.06 MWD+IFR-AK-CAZ-SC(5) 21,596.84 89.04 150.19 7,717.22 7,646.42 -13,645.42 12,085.44 5,951,939.49 361,020.17 1.04 17,721.96 MWD+IFR-AK-CAZ-SC(5) 21,692.60 89.19 150.68 7,718.70 7,647.90 -13,728.70 12,132.68 5,951,855.28 361,065.73 0.54 17,817.68 MWD+IFR-AK-CAZ-SC(5) 21,788.05 88.91 149.65 7,720.28 7,649.48 -13,811.49 12,180.16 5,951,771.56 361,111.54 1.12 17,913.06 MWD+IFR-AK-CAZ-SC(5) 21,883.98 88.99 152.03 7,722.04 7,651.24 -13,895.24 12,226.89 5,951,686.90 361,156.57 2.48 18,008.95 MWD+IFR-AK-CAZ-SC(5) 21,978.50 89.02 149.36 7,723.68 7,652.88 -13,977.65 12,273.15 5,951,603.58 361,201.16 2.82 18,103.42 MWD+IFR-AK-CAZ-SC(5) 22,073.22 88.95 150.24 7,725.36 7,654.56 -14,059.50 12,320.78 5,951,520.80 361,247.14 0.93 18,198.06 MWD+IFR-AK-CAZ-SC(5) 22,168.94 89.05 148.14 7,727.03 7,656.23 -14,141.69 12,369.80 5,951,437.64 361,294.49 2.20 18,293.64 MWD+IFR-AK-CAZ-SC(5) 22,264.29 89.33 146.88 7,728.37 7,657.57 -14,222.11 12,421.01 5,951,356.22 361,344.07 1.35 18,388.69 MWD+IFR-AK-CAZ-SC(5) 22,359.82 89.08 147.87 7,729.70 7,658.90 -14,302.56 12,472.51 5,951,274.76 361,393.94 1.07 18,483.90 MWD+IFR-AK-CAZ-SC(5) 22,453.96 89.12 150.03 7,731.18 7,660.38 -14,383.19 12,521.06 5,951,193.17 361,440.86 2.29 18,577.89 MWD+IFR-AK-CAZ-SC(5) 22,549.61 89.16 150.34 7,732.61 7,661.81 -14,466.17 12,568.61 5,951,109.26 361,486.73 0.33 18,673.48 MWD+IFR-AK-CAZ-SC(5) 22,645.17 88.26 149.56 7,734.77 7,663.97 -14,548.87 12,616.45 5,951,025.63 361,532.89 1.25 18,768.95 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 8 COMPASS 5000.1 Build 74 4111 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 22,739.93 87.49 149.30 7,738.28 7,667.48 -14,630.40 12,664.61 5,950,943.15 361,579.40 0.86 18.863.55 MWD+IFR-AK-CAZ-SC(5) 22,835.16 87.64 148.71 7,742.33 7,671.53 -14,711.96 12,713.60 5,950,860.63 361,626.75 0.64 18,958.56 MWD+IFR-AK-CAZ-SC(5) 22,930.94 87.88 151.06 7,746.07 7,675.27 -14,794.74 12,761.62 5,950,776.91 361,673.09 2.46 19,054.20 MWD+IFR-AK-CAZ-SC(5) 23,025.51 88.72 150.61 7,748.87 7,678.07 -14,877.28 12,807.69 5,950,693.46 361,717.48 1.01 19,148.70 MWD+IFR-AK-CAZ-SC(5) 23,120.96 88.43 152.85 7,751.25 7,680.45 -14,961.32 12,852.88 5,950,608.55 361,760.98 2.37 19,244.12 MWD+IFR-AK-CAZ-SC(5) 23,216.14 88.43 153.99 7,753.86 7,683.06 -15,046.40 12,895.45 5,950,522.63 361,801.83 1.20 19,339.23 MWD+IFR-AK-CAZ-SC(5) 23,310.89 89.09 154.24 7,755.91 7,685.11 -15,131.63 12,936.80 5,950,436.60 361,841.46 0.74 19,433.89 MWD+IFR-AK-CAZ-SC(5) 23,407.12 89.46 154.96 7,757.12 7,686.32 -15,218.55 12,978.08 5,950,348.87 361,880.97 0.84 19,530.02 MWD+IFR-AK-CAZ-SC(5) 23,502.84 89.91 155.52 7,757.65 7,686.85 -15,305.46 13,018.16 5,950,261.17 361,919.31 0.75 19,625.58 MWD+IFR-AK-CAZ-SC(5) 23,597.69 89.98 155.37 7,757.74 7,686.94 -15,391.74 13,057.58 5,950,174.13 361,956.98 0.17 19,720.26 MWD+IFR-AK-CAZ-SC(5) 23,693.15 89.39 155.46 7,758.27 7,687.47 -15,478.54 13,097.30 5,950,086.55 361,994.94 0.63 19,815.55 MWD+IFR-AK-CAZ-SC(5) 23,788.38 89.08 155.17 7,759.54 7,688.74 -15,565.06 13,137.06 5,949,999.26 362,032.96 0.45 19,910.61 MWD+IFR-AK-CAZ-SC(5) 23,883.67 89.19 154.68 7,760.98 7,690.18 -15,651.36 13,177.44 5,949,912.17 362,071.59 0.53 20,005.77 MWD+IFR-AK-CAZ-SC(5) 23,976.81 89.19 155.34 7,762.29 7,691.49 -15,735.77 13,216.79 5,949,827.00 362,109.23 0.71 20,098.77 MWD+IFR-AK-CAZ-SC(5) 24,074.20 89.15 155.36 7,763.70 7,692.90 -15,824.28 13,257.40 5,949,737.70 362,148.06 0.05 20,195.98 MWD+IFR-AK-CAZ-SC(5) 24,169.10 89.04 155.93 7,765.20 7,694.40 -15,910.72 13,296.53 5,949,650.49 362,185.44 0.61 20,290.68 MWD+IFR-AK-CAZ-SC(5) 24,264.29 89.47 156.58 7,766.44 7,695.64 -15,997.84 13,334.86 5,949,562.62 362,222.01 0.82 20,385.59 MWD+IFR-AK-CAZ-SC(5) 24,358.48 89.21 155.51 7,767.53 7,696.73 -16,083.91 13,373.10 5,949,475.81 362,258.51 1.17 20,479.54 MWD+IFR-AK-CAZ-SC(5) 24,454.31 89.92 155.09 7,768.25 7,697.45 -16,170.97 13,413.14 5,949,387.97 362,296.79 0.86 20,575.21 MWD+IFR-AK-CAZ-SC(5) 24,549.57 89.84 153.82 7,768.45 7,697.65 -16,256.92 13,454.22 5,949,301.22 362,336.13 1.34 20,670.38 MWD+IFR-AK-CAZ-SC(5) 24,644.46 89.84 152.45 7,768.72 7,697.92 -16,341.57 13,497.10 5,949,215.74 362,377.30 1.44 20,765.25 MWD+IFR-AK-CAZ-SC(5) 24,739.64 89.71 152.69 7,769.09 7,698.29 -16,426.04 13,540.94 5,949,130.40 362,419.44 0.29 20,860.42 MWD+IFR-AK-CAZ-SC(5) 24,834.39 88.65 152.68 7,770.45 7,699.65 -16,510.22 13,584.42 5,949,045.38 362,461.21 1.12 20,955.16 MWD+IFR-AK-CAZ-SC(5) 24,929.67 89.42 151.44 7,772.05 7,701.25 -16,594.38 13,629.05 5,948,960.35 362,504.14 1.53 21,050.42 MWD+IFR-AK-CAZ-SC(5) 25,025.67 88.23 150.89 7,774.02 7,703.22 -16,678.46 13,675.34 5,948,875.36 362,548.73 1.37 21,146.39 MWD+IFR-AK-CAZ-SC(5) 25,120.44 89.69 150.80 7,775.74 7,704.94 -16,761.20 13,721.50 5,948,791.71 362,593.22 1.54 21,241.12 MWD+IFR-AK-CAZ-SC(5) 25,215.48 89.14 150.36 7,776.71 7,705.91 -16,843.98 13,768.18 5,948,708.02 362,638.22 0.74 21,336.12 MWD+IFR-AK-CAZ-SC(5) 25,311.27 89.23 149.12 7,778.07 7,707.27 -16,926.71 13,816.45 5,948,624.34 362,684.81 1.30 21,431.83 MWD+IFR-AK-CAZ-SC(5) 25,407.05 88.88 150.99 7,779.65 7,708.85 -17,009.69 13,864.25 5,948,540.43 362,730.94 1.99 21,527.54 MWD+IFR-AK-CAZ-SC(5) 25,502.47 88.88 150.35 7,781.52 7,710.72 -17,092.86 13,910.98 5,948,456.34 362,775.98 0.67 21,622.91 MWD+IFR-AK-CAZ-SC(5) 25,599.03 89.05 149.69 7,783.26 7,712.46 -17,176.49 13,959.22 5,948,371.77 362,822.53 0.71 21,719.40 MWD+IFR-AK-CAZ-SC(5) 25,693.88 89.51 151.11 7,784.46 7,713.66 -17,258.95 14,006.07 5,948,288.39 362,867.71 1.57 21,814.20 MWD+IFR-AK-CAZ-SC(5) 25,789.07 89.29 150.65 7,785.45 7,714.65 -17,342.11 14,052.39 5,948,204.33 362,912.35 0.54 21,909.37 MWD+IFR-AK-CAZ-SC(5) 25,883.07 89.33 151.58 7,786.58 7,715.78 -17,424.40 14,097.79 5,948,121.14 362,956.09 0.99 22,003.35 MWD+IFR-AK-CAZ-SC(5) 25,977.58 89.15 151.55 7,787.84 7,717.04 -17,507.50 14,142.79 5,948,037.16 362,999.40 0.19 22,097.85 MWD+IFR-AK-CAZ-SC(5) 26,074.97 89.18 151.43 7,789.26 7,718.46 -17,593.08 14,189.27 5,947,950.68 363,044.15 0.13 22,195.22 MWD+IFR-AK-CAZ-SC(5) 26,169.53 89.71 149.84 7,790.17 7,719.37 -17,675.48 14,235.64 5,947,867.36 363,088.85 1.77 22,289.75 MWD+IFR-AK-CAZ-SC(5) 26,265.79 90.01 150.87 7,790.41 7,719.61 -17,759.14 14,283.25 5,947,782.77 363,134.77 1.11 22,385.97 MWD+IFR-AK-CAZ-SC(5) 26,360.86 89.94 151.82 7,790.45 7,719.65 -17,842.56 14,328.84 5,947,698.45 363,178.67 1.00 22,481.03 MWD+IFR-AK-CAZ-SC(5) 26,456.52 89.77 152.10 7,790.69 7,719.89 -17,926.99 14,373.81 5,947,613.14 363,221.93 0.34 22,576.69 MWD+IFR-AK-CAZ-SC(5) 1/31/2017 4:45:04PM Page 9 COMPASS 5000.1 Build 74 • s • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26,551.60 89.47 151.68 7,791.32 7,720.52 -18,010.86 14,418.60 5,947,528.40 363,265.03 0.54 22,671.77 MWD+IFR-AK-CAZ-SC(5) 26,646.29 88.39 150.05 7,793.09 7,722.29 -18,093.55 14,464.69 5,947,444.81 363,309.45 2.06 22,766.42 MWD+IFR-AK-CAZ-SC(5) 26,741.87 88.02 149.53 7,796.08 7,725.28 -18,176.11 14,512.76 5,947,361.31 363,355.85 0.67 22,861.88 MWD+IFR-AK-CAZ-SC(5) 26,836.93 87.95 149.95 7,799.43 7,728.63 -18,258.16 14,560.64 5,947,278.31 363,402.06 0.45 22,956.81 MWD+IFR-AK-CAZ-SC(5) 26,932.73 87.81 150.25 7,802.97 7,732.17 -18,341.15 14,608.36 5,947,194.39 363,448.10 0.35 23,052.49 MWD+IFR-AK-CAZ-SC(5) 26,983.52 87.85 150.06 7,804.89 7,734.09 -18,385.18 14,633.62 5,947,149.87 363,472.47 0.39 23,103.21 ) 41/2"x 63/4" 27,027.60 87.89 149.89 7,806.53 7,735.73 -18,423.31 14,655.66 5,947,111.30 363,493.74 0.39 23,147.24 MWD+IFR-AK-CAZ-SC(5) 27,089.00 87.89 149.89 7,808.79 7,737.99 -18,476.39 14,686.44 5,947,057.62 363,523.45 0.00 23,208.55 PROJECTED to TD 1/31/2017 4:45:04PM Page 10 COMPASS 5000.1 Build 74 i 0 • E C N O O d 0 - m01 AC), ea It >. = 00 G• f0 '• 4-0 s COsu C) d w O) o C.) c c co w% 4 O O — a) O 3 ! a) d . _ ri vo ti CVO" s O y Y w ( m "CS CD •Q ro m u, t0 � a_) c z° E (DO o cu U 'Cu Om °c n W :;-.. 'C h fay c U E C Q. m O O (c QQ 0 U U cv a) v75W w0oL $ — W 'C 0 ° °; .� c0 >, c ° -X ° a) 11 ° li 4 } ami U) 0 U u) H a� F0000 CC Q M > w O E _J a) a) CD 22 0 Q a) CC w C U • • 216111 27 95 5 RECEIVED FEB 072017 FINAL AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-18 CD5-18 NAD 83 Definitive Survey Report 30 January, 2017 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 CD5-18 Well Position +N/-S 0.00 usft Northing: 5,965,569.79 usft Latitude: 70°18'48.187 N +E/-W 0.00 usft Easting: 1,489,245.23 usft Longitude: 151°13'30.869 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.90 usft Wellbore CD5-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 11/21/2016 17.44 80.81 57,508 Design CD5-18 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.90 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) ,, ,: , ,f (*) 36.90 0.00 0.00 152.00 Survey Program Date 1/30/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 84.00 356.00 CD5-18 Svy1-SLB_GWD70(CD5-18) GYD-GC-SS Gyrodata gyro single shots 12/1/2016 12:59 385.12 2,324.62 CD5-18 Svy2-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/1/2016 9:00:, 2,358.13 2,358.13 CD5-18 Svy3-SLB_INC+Filler(CD5-18) INC+TREND Inclinometer+known azi trend 12/5/2016 9:36:. 2,453.27 15,197.97 CD5-18 Svy4-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/5/2016 9:40: 15,292.25 27,027.60 CD5-18 Svy5-SLB_MWD+GMAG(CD5 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/19/2016 8:24 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 36.90 0.00 0.00 36.90 -33.90 0.00 0.00 5,965,569.79 1,489,245.23 0.00 0.00 UNDEFINED 84.00 0.33 76.87 84.00 13.20 0.03 0.13 5,965,569.82 1,489,245.36 0.70 0.03 GYD-GC-SS(1) 115.00 0.56 29.85 115.00 44.20 0.18 0.29 5,965,569.97 1,489,245.53 1.33 -0.02 GYD-GC-SS(1) 115.90 0.55 30.98 115.90 45.10 0.19 0.30 5,965,569.97 1,489,245.53 1.67 -0.03 y��y �y 20"x 42" AAII IMA 171.00 0.68 127.23 171.00 100.20 0.22 0.70 5,965,569.99 1,489,245.93 1.67 0.13 GYD-GC-SS(1) 264.00 3.85 163.47 263.91 193.11 -3.11 2.02 5,965,566.64 1,489,247.19 3.58 3.70 GYD-GC-SS(1) 356.00 5.42 171.91 355.61 284.81 -10.37 3.51 5,965,559.35 1,489,248.53 1.86 10.81 GYD-GC-SS(1) 385.12 5.16 171.93 384.61 313.81 -13.03 3.89 5,965,556.68 1,489,248.86 0.89 13.33 MWD+IFR-AK-CAZ-SC(2) 477.47 5.47 175.37 476.56 405.76 -21.53 4.83 5,965,548.17 1,489,249.62 0.48 21.28 MWD+IFR-AK-CAZ-SC(2) 568.24 9.11 174.42 566.58 495.78 -33.00 5.88 5,965,536.68 1,489,250.44 4.01 31.89 MWD+IFR-AK-CAZ-SC(2) 1/30/2017 1:54:17PM Page 2 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.8ousft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.8ousft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 661.05 9.36 171.33 658.19 587.39 -47.77 7.73 5,965,521.88 1,489,252.00 0.60 45.81 MWD+IFR-AK-CAZ-SC(2) 751.80 10.03 170.95 747.64 676.84 -62.87 10.09 5,965,506.73 1,489,254.05 0.74 60.25 MWD+IFR-AK-CAZ-SC(2) 845.91 11.75 171.62 840.05 769.25 -80.45 12.77 5,965,489.11 1,489256.38 1.83 77.02 MWD+IFR-AK-CAZ-SC(2) 940.18 12.80 166.75 932.17 861.37 -100.11 16.56 5,965,469.38 1,489,259.77 1.56 96.17 MWD+IFR-AK-CAZ-SC(2) 1,032.91 14.02 165.87 1,022.37 951.57 -121.00 21.66 5,965,448.39 1,489,264.45 1.33 117.01 MWD+IFR-AK-CAZ-SC(2) 1,126.89 15.56 165.25 1,113.23 1,042.43 -144.23 27.65 5,965,425.04 1,489,269.97 1.65 140.33 MWD+IFR-AK-CAZ-SC(2) 1,221.55 16.73 165.69 1,204.16 1,133.36 -169.71 34.25 5,965,399.44 1,489,276.05 1.24 165.92 MWD+IFR-AK-CAZ-SC(2) 1,315.85 20.07 164.25 1,293.63 1,222.83 -198.44 42.00 5,965,370.56 1,489,283.22 3.57 194.93 MWD+IFR-AK-CAZ-SC(2) 1,410.44 21.30 161.77 1,382.12 1,311.32 -230.38 51.78 5,965,338.43 1,489,292.36 1.60 227.72 MWD+IFR-AK-CAZ-SC(2) 1,504.77 25.42 157.37 1,468.71 1,397.91 -265.36 64.94 5,965,303.20 1,489,304.80 4.74 264.78 MWD+IFR-AK-CAZ-SC(2) 1,599.01 27.63 156.00 1,553.02 1,482.22 -304.00 81.61 5,965,264.23 1,489,320.70 2.43 306.73 MWD+IFR-AK-CAZ-SC(2) 1,692.54 28.46 155.81 1,635.57 1,564.77 -344.14 99.56 5,965,223.74 1,489,337.84 0.89 350.60 MWD+IFR-AK-CAZ-SC(2) 1,786.51 31.35 151.26 1,717.03 1,646.23 -386.01 120.50 5,965,181.46 1,489,357.92 3.91 397.40 MWD+IFR-AK-CAZ-SC(2) 1,878.21 34.95 149.01 1,793.79 1,722.99 -429.46 145.50 5,965,137.52 1,489,382.04 4.15 447.50 MWD+IFR-AK-CAZ-SC(2) 1,972.67 36.98 147.62 1,870.24 1,799.44 -476.65 174.65 5,965,089.75 1,489,410.24 2.32 502.85 MWD+IFR-AK-CAZ-SC(2) 2,066.79 38.40 • 145.66 1,944.73 1,873.93 -524.70 206.30 5,965,041.08 1,489,440.91 1.97 560.14 MWD+IFR-AK-CAZ-SC(2) 2,161.07 40.73 142.85 2,017.41 1,946.61 -573.41 241.40 5,964,991.68 1,489,475.02 3.12 619.62 MWD+IFR-AK-CAZ-SC(2) 2,253.23 41.56 137.78 2,086.83 2,016.03 -620.02 280.11 5,964,944.30 1,489,512.78 3.73 678.95 MWD+IFR-AK-CAZ-SC(2) 2,324.62 42.97 136.72 2,139.66 2,068.86 -655.27 312.71 5,964,908.40 1,489,544.66 2.21 725.38 MWD+IFR-AK-CAZ-SC(2) 2,358.13 43.68 136.32 2,164.03 2,093.23 -671.96 328.53 5,964,891.40 1,489,560.14 2.27 747.54 INC+TREND(3) 2,390.93 44.08 135.97 2,187.68 2,116.88 -688.35 344.28 5,964,874.70 1,489,575.56 1.43 769.41 ) 10-3/4"x 13412" 2,453.27 44.85 135.33 2,232.17 2,161.37 -719.58 374.81 5,964,842.86 1,489,605.45 1.43 811.31 MWD+IFR-AK-CAZ-SC(4) 2,546.73 46.88 134.63 2,297.24 2,226.44 -766.98 422.26 5,964,794.52 1,489,651.93 2.24 875.44 MWD+IFR-AK-CAZ-SC(4) 2,641.67 50.17 131.46 2,360.12 2,289.32 -815.48 474.26 5,964,744.98 1,489,702.94 4.27 942.68 MWD+IFR-AK-CAZ-SC(4) 2,736.93 53.19 129.73 2,419.18 2,348.38 -864.09 531.01 5,964,695.25 1,489,758.70 3.48 1,012.24 MWD+IFR-AK-CAZ-SC(4) 2,830.92 55.73 127.99 2,473.82 2,403.02 -912.05 590.57 5,964,646.10 1,489,817.27 3.09 1,082.55 MWD+IFR-AK-CAZ-SC(4) 2,924.89 58.53 126.10 2,524.82 2,454.02 -959.58 653.56 5,964,597.32 1,489,879.29 3.43 1,154.09 MWD+IFR-AK-CAZ-SC(4) 3,020.04 61.73 124.85 2,572.20 2,501.40 -1,007.44 720.76 5,964,548.12 1,489,945.50 3.55 1,227.89 MWD+IFR-AK-CAZ-SC(4) 3,114.60 61.75 124.85 2,616.97 2,546.17 -1,055.04 789.11 5,964,499.16 1,490,012.88 0.02 1,302.00 MWD+IFR-AK-CAZ-SC(4) 3,209.57 61.67 125.50 2,661.98 2,591.18 -1,103.21 857.46 5,964,449.62 1,490,080.25 0.61 1,376.63 MWD+IFR-AK-CAZ-SC(4) 3,304.00 61.66 125.69 2,706.80 2,636.00 -1,151.59 925.05 5,964,399.90 1,490,146.84 0.18 1,451.08 MWD+IFR-AK-CAZ-SC(4) 3,397.53 62.14 125.78 2,750.85 2,680.05 -1,199.77 992.02 5,964,350.38 1,490,212.82 0.52 1,525.06 MWD+IFR-AK-CAZ-SC(4) 3,492.38 62.16 126.38 2,795.16 2,724.36 -1,249.16 1,059.80 5,964,299.64 1,490,279.59 0.56 1,600.49 MWD+IFR-AK-CAZ-SC(4) 3,586.20 62.06 127.05 2,839.05 2,768.25 -1,298.74 1,126.27 5,964,248.74 1,490,345.04 0.64 1,675.47 MWD+IFR-AK-CAZ-SC(4) 3,680.61 62.26 126.72 2,883.14 2,812.34 -1,348.84 1,193.04 5,964,197.30 1,490,410.79 0.37 1,751.06 MWD+IFR-AK-CAZ-SC(4) 3,775.49 62.22 127.74 2,927.33 2,856.53 -1,399.64 1,259.89 5,964,145.17 1,490,476.59 0.95 1,827.29 MWD+IFR-AK-CAZ-SC(4) 3,869.92 62.19 128.32 2,971.37 2,900.57 -1,451.10 1,325.69 5,964,092.40 1,490,541.34 0.54 1,903.62 MWD+IFR-AK-CAZ-SC(4) 3,964.06 62.23 127.97 3,015.26 2,944.46 -1,502.54 1,391.19 5,964,039.66 1,490,605.78 0.33 1,979.79 MWD+IFR-AK-CAZ-SC(4) 4,058.87 62.20 127.39 3,059.45 2,988.65 -1,553.81 1,457.57 5,963,987.06 1,490,671.12 0.54 2,056.22 MWD+IFR-AK-CAZ-SC(4) 1/30/2017 1:54:17PM Page 3 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production [Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4.152.20 61.92 127.74 3.103.18 3,032 38 -1,604.08 1,522.93 5,963,935.49 1,490,735.44 0.45 2,131.29 MWD+IFR-AK-CAZ-SC(4) 4,245.68 62.20 127.38 3,146.98 3,076.18 -1,654.42 1,588.39 5,963,883.85 1,490,799.88 0.45 2,206.47 MWD+IFR-AK-CAZ-SC(4) 4,340.73 62.59 127.00 3,191.03 3,120.23 -1,705.33 1,655.49 5,963,831.60 1,490,865.93 0.54 2,282.93 MWD+IFR-AK-CAZ-SC(4) 4,433.27 62.66 126.08 3,233.58 3,162.78 -1,754.26 1,721.52 5,963,781.36 1,490,930.95 0.89 2,357.12 MWD+IFR-AK-CAZ-SC(4) 4,527.69 62.51 124.82 3,277.06 3,206.26 -1,802.87 1,789.79 5,963,731.38 1,490,998.23 1.20 2,432.10 MWD+IFR-AK-CAZ-SC(4) 4,622.57 62.52 123.88 3,320.84 3,250.04 -1,850.36 1,859.28 5,963,682.51 1,491,066.75 0.88 2,506.66 MWD+IFR-AK-CAZ-SC(4) 4,716.91 62.66 122.99 3,364.28 3,293.48 -1,896.51 1,929.17 5,963,634.97 1,491,135.69 0.85 2,580.21 MWD+IFR-AK-CAZ-SC(4) 4,809.25 62.65 123.34 3,406.69 3,335.89 -1,941.38 1,997.83 5,963,588.73 1,491,203.43 0.34 2,652.06 MWD+IFR-AK-CAZ-SC(4) 4,903.70 62.71 123.35 3,450.04 3,379.24 -1,987.50 2,067.93 5,963,541.20 1,491,272.58 0.06 2,725.70 MWD+IFR-AK-CAZ-SC(4) 4,996.61 62.65 124.29 3,492.68 3,421.88 -2,033.45 2,136.51 5,963,493.89 1,491,340.21 0.90 2,798.46 MWD+IFR-AK-CAZ-SC(4) 5,090.38 62.64 125.01 3,535.77 3,464.97 -2,080.80 2,205.02 5,963,445.17 1,491,407.75 0.68 2,872.43 MWD+IFR-AK-CAZ-SC(4) 5,184.83 62.71 126.11 3,579.13 3,508.33 -2,129.60 2,273.28 5,963,395.02 1,491,475.01 1.04 2,947.57 MWD+IFR-AK-CAZ-SC(4) 5,279.37 62.77 126.26 3,622.43 3,551.63 -2,179.21 2,341.11 5,963,344.05 1,491,541.82 0.15 3,023.22 MWD+IFR-AK-CAZ-SC(4) 5,373.39 62.52 127.28 3,665.63 3,594.83 -2,229.20 2,408.01 5,963,292.73 1,491,607.69 1.00 3,098.76 MWD+IFR-AK-CAZ-SC(4) 5,466.99 62.68 127.56 3,708.71 3,637.91 -2,279.70 2,474.00 5,963,240.92 1,491,672.65 0.32 3,174.33 MWD+IFR-AK-CAZ-SC(4) 5,561.53 62.61 127.51 3,752.15 3,681.35 -2,330.85 2,540.59 5,963,188.43 1,491,738.19 0.09 3,250.76 MWD+IFR-AK-CAZ-SC(4) 5,656.00 62.58 127.23 3,795.63 3,724.83 -2,381.76 2,607.24 5,963,136.20 1,491,803.80 0.27 3,326.99 MWD+IFR-AK-CAZ-SC(4) 5,748.79 62.64 126.73 3,838.32 3,767.52 -2,431.32 2,673.06 5,963,085.33 1,491,868.60 0.48 3,401.65 MWD+IFR-AK-CAZ-SC(4) 5,843.84 62.78 125.93 3,881.90 3,811.10 -2,481.36 2,741.11 5,963,033.93 1,491,935.62 0.76 3,477.78 MWD+IFR-AK-CAZ-SC(4) 5,937.70 62.68 124.56 3,924.91 3,854.11 -2,529.50 2,809.24 5,962,984.43 1,492,002.77 1.30 3,552.28 MWD+IFR-AK-CAZ-SC(4) 6,031.84 62.71 124.40 3,968.09 3,897.29 -2,576.86 2,878.19 5,962,935.70 1,492,070.75 0.15 3,626.46 MWD+IFR-AK-CAZ-SC(4) 6,126.23 62.68 125.29 4,011.39 3,940.59 -2,624.78 2,947.03 5,962,886.41 1,492,138.60 0.84 3,701.09 MWD+IFR-AK-CAZ-SC(4) 6,220.52 62.75 125.14 4,054.62 3,983.82 -2,673.10 3,015.49 5,962,836.72 1,492,206.07 0.16 3,775.90 MWD+IFR-AK-CAZ-SC(4) 6,315.29 62.74 125.30 4,098.02 4,027.22 -2,721.69 3,084.32 5,962,786.76 1,492,273.90 0.15 3,851.11 MWD+IFR-AK-CAZ-SC(4) 6,410.03 62.68 125.64 4,141.45 4,070.65 -2,770.54 3,152.89 5,962,736.54 1,492,341.47 0.33 3,926.44 MWD+IFR-AK-CAZ-SC(4) 6,504.45 62.75 126.69 4,184.74 4,113.94 -2,820.06 3,220.63 5,962,685.67 1,492,408.20 0.99 4,001.96 MWD+IFR-AK-CAZ-SC(4) 6,597.88 62.69 127.68 4,227.56 4,156.76 -2,870.25 3,286.79 5,962,634.16 1,492,473.32 0.94 4,077.33 MWD+IFR-AK-CAZ-SC(4) 6,692.85 62.69 128.27 4,271.13 4,200.33 -2,922.17 3,353.31 5,962,580.92 1,492,538.78 0.55 4,154.41 MWD+IFR-AK-CAZ-SC(4) 6,786.89 62.65 127.74 4,314.31 4,243.51 -2,973.61 3,419.13 5,962,528.17 1,492,603.55 0.50 4,230.73 MWD+IFR-AK-CAZ-SC(4) 6,881.59 62.64 128.01 4,357.82 4,287.02 -3,025.25 3,485.53 5,962,475.20 1,492,668.89 0.25 4,307.49 MWD+IFR-AK-CAZ-SC(4) 6,975.69 62.65 128.04 4,401.06 4,330.26 -3,076.74 3,551.36 5,962,422.41 1,492,733.67 0.03 4,383.86 MWD+IFR-AK-CAZ-SC(4) 7,070.09 62.69 127.29 4,444.41 4,373.61 -3,127.98 3,617.75 5,962,369.84 1,492,799.00 0.71 4,460.27 MWD+IFR-AK-CAZ-SC(4) 7,165.37 62.72 126.10 4,488.10 4,417.30 -3,178.57 3,685.64 5,962,317.90 1,492,865.86 1.11 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,259.17 62.62 125.76 4,531.16 4,460.36 -3,227.47 3,753.11 5,962,267.65 1,492,932.33 0.34 4,611.67 MWD+IFR-AK-CAZ-SC(4) 7,354.03 62.19 125.10 4,575.11 4,504.31 -3,276.21 3,821.61 5,962,217.55 1,492,999.83 0.77 4,686.86 MWD+IFR-AK-CAZ-SC(4) 7,447.25 62.17 124.98 4,618.61 4,547.81 -3,323.54 3,889.12 5,962,168.87 1,493,066.36 0.12 4,760.34 MWD+IFR-AK-CAZ-SC(4) 7,541.72 62.23 124.33 4,662.67 4,591.87 -3,371.06 3,957.86 5,962,119.98 1,493,134.12 0.61 4,834.57 MWD+IFR-AK-CAZ-SC(4) 7,636.59 62.23 124.26 4,706.87 4,636.07 -3,418.36 4,027.21 5,962,071.30 1,493,202.50 0.07 4,908.89 MWD+IFR-AK-CAZ-SC(4) 7,730.82 62.22 125.34 4,750.78 4,679.98 -3,465.94 4,095.67 5,962,022.35 1,493,269.98 1.01 4,983.04 MWD+IFR-AK-CAZ-SC(4) 7,824.87 62.23 126.24 4,794.61 4,723.81 -3,514.60 4,163.17 5,961,972.34 1,493,336.49 0.85 5,057.70 MWD+IFR-AK-CAZ-SC(4) 1/30/2017 1:54:17PM Page 4 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,920.41 62.17 126.71 4,839.17 4,768.37 -3,564.84 4,231 12 5,961,920.75 1,493,403.41 0.44 5,133.96 MWD+IFR-AK-CAZ-SC(4) 8,015.16 62.14 126.65 4,883.43 4,812.63 -3,614.89 4,298.31 5,961,869.37 1,493,469.58 0.06 5,209.69 MWD+IFR-AK-CAZ-SC(4) 8,108.34 62.17 126.43 4,926.95 4,856.15 -3,663.94 4,364.51 5,961,818.99 1,493,534.77 0.21 5,284.08 MWD+IFR-AK-CAZ-SC(4) 8,201.17 62.19 126.06 4,970.27 4,899.47 -3,712.48 4,430.72 5,961,769.13 1,493,599.99 0.35 5,358.03 MWD+IFR-AK-CAZ-SC(4) 8,295.29 62.16 125.59 5,014.21 4,943.41 -3,761.20 4,498.21 5,961,719.07 1,493,666.48 0.44 5,432.73 MWD+IFR-AK-CAZ-SC(4) 8,389.10 62.14 125.89 5,058.03 4,987.23 -3,809.65 4,565.54 5,961,669.28 1,493,732.81 0.28 5,507.11 MWD+IFR-AK-CAZ-SC(4) 8,483.45 62.13 125.36 5,102.13 5,031.33 -3,858.24 4,633.34 5,961,619.34 1,493,799.61 0.50 5,581.84 MWD+IFR-AK-CAZ-SC(4) 8,576.79 62.23 124.44 5,145.69 5,074.89 -3,905.47 4,701.04 5,961,570.76 1,493,866.34 0.88 5,655.33 MWD+IFR-AK-CAZ-SC(4) 8,671.18 62.28 124.61 5,189.63 5,118.83 -3,952.81 4,769.86 5,961,522.04 1,493,934.19 0.17 5,729.44 MWD+IFR-AK-CAZ-SC(4) 8,765.50 62.69 124.88 5,233.21 5,162.41 -4,000.49 4,838.60 5,961,473.00 1,494,001.95 0.50 5,803.81 MWD+IFR-AK-CAZ-SC(4) 8,859.72 62.73 125.83 5,276.41 5,205.61 -4,048.94 4,906.89 5,961,423.18 1,494,069.25 0.90 5,878.65 MWD+IFR-AK-CAZ-SC(4) 8,953.36 62.68 125.97 5,319.35 5,248.55 -4,097.73 4,974.30 5,961,373.05 1,494,135.65 0.14 5,953.38 MWD+IFR-AK-CAZ-SC(4) 9,047.60 62.63 126.61 5,362.64 5,291.84 -4,147.28 5,041.77 5,961,322.16 1,494,202.11 0.61 6,028.80 MWD+4FR-AK-CAZ-SC(4) 9,142.34 62.65 125.31 5,406.18 5,335.38 -4,196.69 5,109.87 5,961,271.39 1,494,269.20 1.22 6,104.39 MWD+IFR-AK-CAZ-SC(4) 9,236.31 62.64 124.96 5,449.36 5,378.56 -4,244.72 5,178.13 5,961,222.00 1,494,336.47 0.33 6,178.85 MWD+IFR-AK-CAZ-SC(4) 9,329.94 62.72 125.21 5,492.33 5,421.53 -4,292.53 5,246.20 5,961,172.82 1,494,403.56 0.25 6,253.02 MWD+IFR-AK-CAZ-SC(4) 9,423.56 62.62 124.36 5,535.31 5,464.51 -4,339.98 5,314.51 5,961,124.01 1,494,470.89 0.81 6,326.99 MWD+IFR-AK-CAZ-SC(4) 9,518.44 62.65 124.55 5,578.93 5,508.13 -4,387.65 5,383.99 5,961,074.96 1,494,539.39 0.18 6,401.70 MWD+IFR-AK-CAZ-SC(4) 9,613.17 62.72 124.33 5,622.40 5,551.60 -4,435.25 5,453.40 5,961,025.97 1,494,607.83 0.22 6,476.31 MWD+IFR-AK-CAZ-SC(4) 9,707.49 62.58 124.36 5,665.73 5,594.93 -4,482.52 5,522.57 5,960,977.33 1,494,676.03 0.15 6,550.52 MWD+IFR-AK-CAZ-SC(4) 9,801.90 62.72 124.09 5,709.10 5,638.30 -4,529.68 5,591.91 5,960,928.78 1,494,744.40 0.29 6,624.71 MWD+IFR-AK-CAZ-SC(4) 9,895.12 62.71 125.15 5,751.84 5,681.04 -4,576.75 5,660.08 5,960,880.35 1,494,811.61 1.01 6,698.28 MWD+IFR-AK-CAZ-SC(4) 9,989.24 62.85 125.63 5,794.89 5,724.09 -4,625.22 5,728.32 5,960,830.52 1,494,878.84 0.48 6,773.11 MWD+IFR-AK-CAZ-SC(4) 10,081.30 62.75 127.14 5,836.97 5,766.17 -4,673.79 5,794.23 5,960,780.64 1,494,943.76 1.46 6,846.94 MWD+IFR-AK-CAZ-SC(4) 10,175.34 62.79 127.04 5,880.00 5,809.20 -4,724.22 5,860.93 5,960,728.88 1,495,009.43 0.10 6,922.78 MWD+IFR-AK-CAZ-SC(4) 10,269.23 62.79 126.86 5,922.93 5,852.13 -4,774.41 5,927.66 5,960,677.36 1,495,075.13 0.17 6,998.43 MWD+IFR-AK-CAZ-SC(4) 10,363.59 62.59 127.69 5,966.23 5,895.43 -4,825.19 5,994.38 5,960,625.25 1,495,140.81 0.81 7,074.58 MWD+IFR-AK-CAZ-SC(4) 10,455.95 62.70 127.43 6,008.67 5,937.87 -4,875.20 6,059.41 5,960,573.95 1,495,204.81 0.28 7,149.26 MWD+IFR-AK-CAZ-SC(4) 10,550.12 62.65 126.87 6,051.89 5,981.09 -4,925.72 6,126.09 5,960,522.10 1,495,270.46 0.53 7,225.18 MWD+IFR-AK-CAZ-SC(4) 10,643.93 62.55 126.37 6,095.07 6,024.27 -4,975.40 6,192.93 5,960,471.09 1,495,336.28 0.49 7,300.42 MWD+IFR-AK-CAZ-SC(4) 10,738.33 62.62 126.27 6,138.53 6,067.73 -5,025.03 6,260.45 5,960,420.11 1,495,402.78 0.12 7,375.95 MWD+IFR-AK-CAZ-SC(4) 10,831.70 62.66 126.53 6,181.44 6,110.64 -5,074.24 6,327.20 5,960,369.57 1,495,468.52 0.25 7,450.73 MWD+IFR-AK-CAZ-SC(4) 10,924.78 62.70 125.50 6,224.16 6,153.36 -5,122.87 6,394.09 5,960,319.61 1,495,534.41 0.98 7,525.07 MWD+IFR-AK-CAZ-SC(4) 11,019.12 62.69 126.13 6,267.44 6,196.64 -5,171.92 6,462.07 5,960,269.20 1,495,601.38 0.59 7,600.29 MWD+IFR-AK-CAZ-SC(4) 11,113.38 62.15 126.32 6,311.08 6,240.28 -5,221.30 6,529.46 5,960,218.49 1,495,667.77 0.60 7,675.53 MWD+IFR-AK-CAZ-SC(4) 11,205.90 62.24 126.56 6,354.24 6,283.44 -5,269.91 6,595.30 5,960,168.56 1,495,732.61 0.25 7,749.36 MWD+IFR-AK-CAZ-SC(4) 11,300.07 62.13 127.17 6,398.18 6,327.38 -5,319.87 6,661.94 5,960,117.27 1,495,798.22 0.58 7,824.76 MWD+IFR-AK-CAZ-SC(4) 11,393.17 62.20 126.83 6,441.65 6,370.85 -5,369.42 6,727.69 5,960,066.41 1,495,862.96 0.33 7,899.37 MWD+IFR-AK-CAZ-SC(4) 11,486.75 62.17 126.57 6,485.32 6,414.52 -5,418.88 6,794.05 5,960,015.63 1,495,928.30 0.25 7,974.20 MWD+IFR-AK-CAZ-SC(4) 11,580.56 62.20 127.18 6,529.09 6,458.29 -5,468.67 6,860.42 5,959,964.52 1,495,993.65 0.58 8,049.32 MWD+IFR-AK-CAZ-SC(4) 1/30/2017 1:54:17PM Page 5 COMPASS 5000.1 Build 74 • s SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 11,674.78 62.27 127.64 6,572.98 6,502.18 -5,519.32 6,926.64 5,959,912.55 1,496,058.84 0.44 8,125.13 MWD+IFR-AK-CAZ-SC(4) 11,768.18 62.34 128.29 6,616.39 6,545.59 -5,570.20 6,991.84 5,959,860.37 1,496,122.99 0.62 8,200.66 MWD+IFR-AK-CAZ-SC(4) 11,862.91 62.14 129.15 6,660.51 6,589.71 -5,622.63 7,057.24 5,959,806.64 1,496,187.32 0.83 8,277.66 MWD+IFR-AK-CAZ-SC(4) 11,956.92 62.20 128.64 6,704.40 6,633.60 -5,674.83 7,121.95 5,959,753.15 1,496,250.96 0.48 8,354.13 MWD+IFR-AK-CAZ-SC(4) 12,049.21 62.18 128.64 6,747.46 6,676.66 -5,725.80 7,185.71 5,959,700.91 1,496,313.68 0.02 8,429.07 MWD+IFR-AK-CAZ-SC(4) 12,142.96 62.21 129.84 6,791.19 6,720.39 -5,778.26 7,249.93 5,959,647.17 1,496,376.83 1.13 8,505.54 MWD+IFR-AK-CAZ-SC(4) 12,236.77 62.58 130.38 6,834.66 6,763.86 -5,831.81 7,313.51 5,959,592.35 1,496,439.31 0.64 8,582.67 MWD+IFR-AK-CAZ-SC(4) 12,330.84 62.63 130.52 6,877.95 6,807.15 -5,886.00 7,377.07 5,959,536.90 1,496,501.76 0.14 8,660.35 MWD+IFR-AK-CAZ-SC(4) 12,424.49 62.66 132.26 6,920.98 6,850.18 -5,940.99 7,439.47 5,959,480.67 1,496,563.03 1.65 8,738.20 MWD+IFR-AK-CAZ-SC(4) 12,518.25 62.69 132.98 6,964.02 6,893.22 -5,997.40 7,500.76 5,959,423.04 1,496,623.17 0.68 8,816.78 MWD+IFR-AK-CAZ-SC(4) 12,611.31 62.62 133.38 7,006.77 6,935.97 -6,053.96 7,561.04 5,959,365.28 1,496,682.30 0.39 8,895.02 MWD+IFR-AK-CAZ-SC(4) 12,705.28 62.56 134.18 7,050.03 6,979.23 -6,111.68 7,621.27 5,959,306.37 1,496,741.35 0.76 8,974.26 MWD+IFR-AK-CAZ-SC(4) 12,798.86 62.41 133.92 7,093.26 7,022.46 -6,169.38 7,680.92 5,959,247.48 1,496,799.82 0.29 9,053.22 MWD+IFR-AK-CAZ-SC(4) 12,892.88 62.38 134.29 7,136.83 7,066.03 -6,227.37 7,740.75 5,959,188.30 1,496,858.46 0.35 9,132.50 MWD+IFR-AK-CAZ-SC(4) 12,986.81 63.09 134.50 7,179.86 7,109.06 -6,285.78 7,800.40 5,959,128.71 1,496,916.93 0.78 9,212.09 MWD+IFR-AK-CAZ-SC(4) 13,080.34 63.18 134.12 7,222.12 7,151.32 -6,344.07 7,860.11 5,959,069.24 1,496,975.44 0.37 9,291.58 MWD+IFR-AK-CAZ-SC(4) 13,174.14 64.60 135.30 7,263.40 7,192.60 -6,403.32 7,919.96 5,959,008.79 1,497,034.08 1.89 9,371.99 MWD+IFR-AK-CAZ-SC(4) 13,268.65 65.84 136.73 7,303.02 7,232.22 -6,465.06 7,979.54 5,958,945.87 1,497,092.41 1.90 9,454.48 MWD+IFR-AK-CAZ-SC(4) 13,361.45 67.88 137.74 7,339.48 7,268.68 -6,527.71 8,037.48 5,958,882.07 1,497,149.06 2.42 9,536.99 MWD+IFR-AK-CAZ-SC(4) 13,455.04 70.12 138.25 7,373.02 7,302.22 -6,592.63 8,095.94 5,958,815.99 1,497,206.21 2.45 9,621.77 MWD+IFR-AK-CAZ-SC(4) 13,549.20 72.03 139.62 7,403.56 7,332.76 -6,659.79 8,154.44 5,958,747.67 1,497,263.34 2.45 9,708.52 MWD+IFR-AK-CAZ-SC(4) 13,643.10 73.37 141.03 7,431.48 7,360.68 -6,728.79 8,211.67 5,958,677.54 1,497,319.17 2.02 9,796.32 MWD+IFR-AK-CAZ-SC(4) 13,738.19 75.03 142.52 7,457.38 7,386.58 -6,800.67 8,268.28 5,958,604.54 1,497,374.31 2.31 9,886.36 MWD+IFR-AK-CAZ-SC(4) 13,830.52 76.88 143.97 7,479.78 7,408.98 -6,872.43 8,321.87 5,958,531.72 1,497,426.44 2.52 9,974.88 MWD+IFR-AK-CAZ-SC(4) 13,924.72 79.22 145.65 7,499.29 7,428.49 -6,947.74 8,374.97 5,958,455.36 1,497,478.01 3.04 10,066.30 MWD+IFR-AK-CAZ-SC(4) 14,018.68 81.68 146.65 7,514.88 7,444.08 -7,024.69 8,426.58 5,958,377.40 1,497,528.05 2.82 10,158.47 MWD+IFR-AK-CAZ-SC(4) 14,113.21 83.32 146.90 7,527.21 7,456.41 -7,103.09 8,477.93 5,958,297.99 1,497,577.81 1.75 10,251.80 MWD+IFR-AK-CAZ-SC(4) 14,204.97 84.50 149.24 7,536.95 7,466.15 -7,180.52 8,526.18 5,958,219.61 1,497,624.49 2.84 10,342.82 MWD+IFR-AK-CAZ-SC(4) 14,299.09 84.99 150.16 7,545.57 7,474.77 -7,261.44 8,573.46 5,958,137.76 1,497,670.13 1.10 10,436.47 MWD+IFR-AK-CAZ-SC(4) 14,393.31 85.21 150.93 7,553.62 7,482.82 -7,343.18 8,619.62 5,958,055.11 1,497,714.63 0.85 10,530.31 MWD+IFR-AK-CAZ-SC(4) 14,487.43 84.36 150.55 7,562.17 7,491.37 -7,424.95 8,665.44 5,957,972.44 1,497,758.79 0.99 10,624.02 MWD+IFR-AK-CAZ-SC(4) 14,580.27 84.56 149.74 7,571.14 7,500.34 -7,505.09 8,711.44 5,957,891.39 1,497,803.16 0.89 10,716.37 MWD+IFR-AK-CAZ-SC(4) 14,674.94 84.36 148.61 7,580.28 7,509.48 -7,586.01 8,759.72 5,957,809.53 1,497,849.80 1.21 10,810.49 MWD+IFR-AK-CAZ-SC(4) 14,767.23 84.00 147.75 7,589.63 7,518.83 -7,664.02 8,808.13 5,957,730.56 1,497,896.63 1.01 10,902.09 MWD+IFR-AK-CAZ-SC(4) 14,861.19 84.00 148.38 7,599.46 7,528.66 -7,743.32 8,857.56 5,957,650.29 1,497,944.44 0.67 10,995.32 MWD+IFR-AK-CAZ-SC(4) 14,953.92 84.12 148.34 7,609.05 7,538.25 -7,821.85 8,905.94 5,957,570.81 1,497,991.23 0.14 11,087.36 MWD+IFR-AK-CAZ-SC(4) 15,048.67 84.41 147.89 7,618.52 7,547.72 -7,901.90 8,955.74 5,957,489.78 1,498,039.41 0.56 11,181.42 MWD+IFR-AK-CAZ-SC(4) 15,142.04 86.13 147.66 7,626.22 7,555.42 -7,980.61 9,005.36 5,957,410.09 1,498,087.42 1.86 11,274.22 MWD+IFR-AK-CAZ-SC(4) 15,197.97 86.07 147.95 7,630.02 7,559.22 -8,027.83 9,035.09 5,957,362.28 1,498,116.20 0.53 11,329.87 MWD+IFR-AK-CAZ-SC(4) 15,251.01 86.89 148.21 7,633.28 7,562.48 -8,072.77 9,063.08 5,957,316.80 1,498,143.27 1.63 11,382.69 OT an Actual Survey 1/30/2017 1:54:17PM Page 6 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 r 7-5/8"x 9-7/8"by 11" 15,292.25 87.53 148.42 7,635.29 7,564.49 -8,107.82 9,084.71 5,957,281.32 1,498,164.20 1.63 11,423.79 MWD+IFR-AK-CAZ-SC(5) 15,310.37 87.96 148.82 7,636.00 7,565.20 -8,123.28 9,094.14 5,957,265.67 1,498,173.31 3.24 11,441.87 MWD+IFR-AK-CAZ-SC(5) 15,405.61 90.02 149.98 7,637.68 7,566.88 -8,205.24 9,142.61 5,957,182.76 1,498,220.12 2.48 11,536.99 MWD+IFR-AK-CAZ-SC(5) 15,501.26 89.31 148.89 7,638.24 7,567.44 -8,287.59 9,191.24 5,957,099.45 1,498,267.08 1.36 11,632.54 MWD+IFR-AK-CAZ-SC(5) 15,596.83 89.53 149.45 7,639.20 7,568.40 -8,369.65 9,240.22 5,957,016.43 1,498,314.39 0.63 11,727.99 MWD+IFR-AK-CAZ-SC(5) 15,691.63 89.39 150.70 7,640.10 7,569.30 -8,451.81 9,287.51 5,956,933.34 1,498,360.01 1.33 11,822.73 MWD+IFR-AK-CAZ-SC(5) 15,787.06 89.50 149.22 7,641.02 7,570.22 -8,534.41 9,335.28 5,956,849.80 1,498,406.11 1.56 11,918.09 MWD+IFR-AK-CAZ-SC(5) 15,882.48 89.28 148.90 7,642.04 7,571.24 -8,616.25 9,384.34 5,956,766.99 1,498,453.50 0.41 12,013.38 MWD+IFR-AK-CAZ-SC(5) 15,977.32 89.47 149.22 7,643.07 7,572.27 -8,697.59 9,433.09 5,956,684.70 1,498,500.61 0.39 12,108.09 MWD+IFR-AK-CAZ-SC(5) 16,072.60 89.36 147.08 7,644.05 7,573.25 -8,778.52 9,483.37 5,956,602.78 1,498,549.24 2.25 12,203.14 MWD+IFR-AK-CAZ-SC(5) 16,167.92 89.36 147.59 7,645.11 7,574.31 -8,858.75 9,534.81 5,956,521.53 1,498,599.05 0.54 12,298.14 MWD+IFR-AK-CAZ-SC(5) 16,263.96 89.53 147.68 7,646.04 7,575.24 -8,939.87 9,586.22 5,956,439.40 1,498,648.82 0.20 12,393.90 MWD+IFR-AK-CAZ-SC(5) 16,358.46 89.81 148.90 7,646.59 7,575.79 -9,020.26 9,635.89 5,956,358.03 1,498,696.85 1.32 12,488.19 MWD+IFR-AK-CAZ-SC(5) 16,454.76 89.84 150.14 7,646.88 7,576.08 -9,103.25 9,684.73 5,956,274.08 1,498,744.01 1.29 12,584.40 MWD+IFR-AK-CAZ-SC(5) 16,549.18 90.15 149.70 7,646.89 7,576.09 -9,184.96 9,732.06 5,956,191.45 1,498,789.68 0.57 12,678.76 MWD+IFR-AK-CAZ-SC(5) 16,644.62 90.35 151.03 7,646.47 7,575.67 -9,267.91 9,779.25 5,956,107.57 1,498,835.19 1.41 12,774.16 MWD+IFR-AK-CAZ-SC(5) 16,739.56 90.46 150.72 7,645.80 7,575.00 -9,350.84 9,825.46 5,956,023.73 1,498,879.71 0.35 12,869.08 MWD+IFR-AK-CAZ-SC(5) 16,835.34 90.19 152.06 7,645.26 7,574.46 -9,434.92 9,871.32 5,955,938.74 1,498,923.87 1.43 12,964.85 MWD+IFR-AK-CAZ-SC(5) 16,929.99 89.35 154.61 7,645.64 7,574.84 -9,519.50 9,913.79 5,955,853.34 1,498,964.63 2.84 13,059.46 MWD+IFR-AK-CAZ-SC(5) 17,025.88 89.30 155.47 7,646.77 7,575.97 -9,606.43 9,954.25 5,955,765.62 1,499,003.33 0.90 13,155.21 MWD+IFR-AK-CAZ-SC(5) 17,121.16 88.72 152.90 7,648.41 7,577.61 -9,692.18 9,995.73 5,955,679.06 1,499,043.07 2.76 13,250.40 MWD+IFR-AK-CAZ-SC(5) 17,217.20 87.05 152.17 7,651.96 7,581.16 -9,777.33 10,040.00 5,955,593.03 1,499,085.61 1.90 13,346.36 MWD+IFR-AK-CAZ-SC(5) 17,312.13 85.70 152.37 7,657.96 7,587.16 -9,861.19 10,084.08 5,955,508.31 1,499,127.99 1.44 13,441.10 MWD+IFR-AK-CAZ-SC(5) 17,407.49 85.86 151.83 7,664.98 7,594.18 -9,945.24 10,128.58 5,955,423.39 1,499,170.78 0.59 13,536.20 MWD+IFR-AK-CAZ-SC(5) 17,502.89 85.85 150.69 7,671.87 7,601.07 -10,028.66 10,174.33 5,955,339.07 1,499,214.84 1.19 13,631.34 MWD+IFR-AK-CAZ-SC(5) 17,596.52 88.67 150.46 7,676.35 7,605.55 -10,110.11 10,220.27 5,955,256.72 1,499,259.13 3.02 13,724.83 MWD+IFR-AK-CAZ-SC(5) 17,691.34 89.61 149.46 7,677.77 7,606.97 -10,192.19 10,267.73 5,955,173.71 1,499,304.93 1.45 13,819.57 MWD+IFR-AK-CAZ-SC(5) 17,787.19 89.57 148.51 7,678.46 7,607.66 -10,274.33 10,317.12 5,955,090.60 1,499,352.65 0.99 13,915.29 MWD+IFR-AK-CAZ-SC(5) 17,881.86 89.39 147.68 7,679.32 7,608.52 -10,354.69 10,367.15 5,955,009.25 1,499,401.05 0.90 14,009.73 MWD+IFR-AK-CAZ-SC(5) 17,977.44 89.16 149.07 7,680.53 7,609.73 -10,436.07 10,417.26 5,954,926.88 1,499,449.51 1.47 14,105.11 MWD+IFR-AK-CAZ-SC(5) 18,073.08 88.59 150.28 7,682.40 7,611.60 -10,518.61 10,465.54 5,954,843.40 1,499,496.11 1.40 14,200.65 MWD+IFR-AK-CAZ-SC(5) 18,168.71 88.64 151.09 7,684.71 7,613.91 -10,601.97 10,512.35 5,954,759.12 1,499,541.23 0.85 14,296.23 MWD+IFR-AK-CAZ-SC(5) 18,263.72 88.60 150.34 7,687.00 7,616.20 -10,684.81 10,558.81 5,954,675.36 1,499,586.01 0.79 14,391.19 MWD+IFR-AK-CAZ-SC(5) 18,359.06 88.60 150.72 7,689.33 7,618.53 -10,767.79 10,605.70 5,954,591.46 1,499,631.21 0.40 14,486.47 MWD+IFR-AK-CAZ-SC(5) 18,453.76 89.19 151.40 7,691.16 7,620.36 -10,850.65 10,651.52 5,954,507.71 1,499,675.35 0.95 14,581.14 MWD+IFR-AK-CAZ-SC(5) 18,549.17 89.81 150.79 7,691.99 7,621.19 -10,934.17 10,697.63 5,954,423.28 1,499,719.77 0.91 14,676.53 MWD+IFR-AK-CAZ-SC(5) 18,644.58 89.77 150.83 7,692.34 7,621.54 -11,017.46 10,744.16 5,954,339.07 1,499,764.61 0.06 14,771.92 MWD+IFR-AK-CAZ-SC(5) 18,739.51 89.73 150.42 7,692.76 7,621.96 -11,100.18 10,790.73 5,954,255.44 1,499,809.50 0.43 14,866.82 MWD+IFR-AK-CAZ-SC(5) 18,834.48 89.73 150.20 7,693.20 7,622.40 -11,182.68 10,837,77 5,954,172.01 1,499,854.86 0.23 14,961.75 MWD+IFR-AK-CAZ-SC(5) 1/30/2017 1:54:17PM Page 7 COMPASS 5000.1 Build 74 0 • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) (°/10(') (ft) Survey Tool Name 18,929.83 90.22 150.03 7,693.24 7,622.44 -11,265.35 10,885.27 5,954,088.41 1,499,900.69 0.54 15,057.04 MWD+IFR-AK-CAZ-SC(5) 19,025.16 90.33 150.01 7,692.79 7,621.99 -11,347.93 10,932.91 5,954,004.90 1,499,946.65 0.12 15,152.32 MWD+IFR-AK-CAZ-SC(5) 19,120.20 89.93 151.41 7,692.57 7,621.77 -11,430.82 10,979.41 5,953,921.10 1,499,991.47 1.53 15,247.33 MWD+IFR-AK-CAZ-SC(5) 19,214.31 90.04 152.14 7,692.60 7,621.80 -11,513.74 11,023.91 5,953,837.30 1,500,034.29 0.78 15,341.44 MWD+IFR-AK-CAZ-SC(5) 19,310.29 90.16 152.74 7,692.43 7,621.63 -11,598.82 11,068.32 5,953,751.34 1,500,076.98 0.64 15,437.42 MWD+IFR-AK-CAZ-SC(5) 19,407.13 89.52 154.82 7,692.70 7,621.90 -11,685.69 11,111.10 5,953,663.64 1,500,118.00 2.25 15,534.20 MWD+IFR-AK-CAZ-SC(5) 19,501.32 89.81 154.78 7,693.25 7,622.45 -11,770.92 11,151.21 5,953,577.63 1,500,156.37 0.31 15,628.28 MWD+IFR-AK-CAZ-SC(5) 19,595.70 89.74 156.91 7,693.62 7,622.82 -11,857.03 11,189.83 5,953,490.76 1,500,193.25 2.26 15,722.44 MWD+IFR-AK-CAZ-SC(5) 19,691.17 89.82 153.91 7,693.99 7,623.19 -11,943.83 11,229.55 5,953,403.19 1,500,231.21 3.14 15,817.73 MWD+IFR-AK-CAZ-SC(5) 19,786.12 88.97 153.85 7,694.99 7,624.19 -12,029.08 11,271.35 5,953,317.12 1,500,271.28 0.90 15,912.62 MWD+IFR-AK-CAZ-SC(5) 19,881.65 89.19 153.85 7,696.52 7,625.72 -12,114.82 11,313.44 5,953,230.56 1,500,311.64 0.23 16,008.09 MWD+IFR-AK-CAZ-SC(5) 19,976.05 89.12 154.41 7,697.92 7,627.12 -12,199.75 11,354.63 5,953,144.82 1,500,351.11 0.60 16,102.41 MWD+IFR-AK-CAZ-SC(5) 20,071.07 89.09 155.35 7,699.40 7,628.60 -12,285.77 11,394.96 5,953,058.01 1,500,389.70 0.99 16,197.30 MWD+IFR-AK-CAZ-SC(5) 20,167.40 88.92 158.37 7,701.07 7,630.27 -12,374.33 11,432.81 5,952,968.72 1,500,425.75 3.14 16,293.26 MWD+IFR-AK-CAZ-SC(5) 20,261.02 89.12 154.78 7,702.67 7,631.87 -12,460.20 11,470.01 5,952,882.12 1,500,461.22 3.84 16,386.55 MWD+IFR-AK-CAZ-SC(5) 20,356.17 89.26 153.21 7,704.02 7,633.22 -12,545.71 11,511.73 5,952,795.79 1,500,501.20 1.66 16,481.63 MWD+IFR-AK-CAZ-SC(5) 20,451.20 89.26 154.33 7,705.25 7,634.45 -12,630.94 11,553.72 5,952,709.74 1,500,541.46 1.18 16,576.61 MWD+IFR-AK-CAZ-SC(5) 20,547.02 89.16 153.23 7,706.57 7,635.77 -12,716.90 11,596.05 5,952,622.96 1,500,582.05 1.15 16,672.37 MWD+IFR-AK-CAZ-SC(5) 20,641.85 88.94 154.09 7,708.14 7,637.34 -12,801.87 11,638.12 5,952,537.16 1,500,622.40 0.94 16,767.15 MWD+IFR-AK-CAZ-SC(5) 20,737.66 89.22 153.51 7,709.68 7,638.88 -12,887.82 11,680.42 5,952,450.38 1,500,662.95 0.67 16,862.90 MWD+IFR-AK-CAZ-SC(5) 20,833.68 89.19 152.67 7,711.01 7,640.21 -12,973.44 11,723.87 5,952,363.91 1,500,704.67 0.88 16,958.89 MWD+IFR-AK-CAZ-SC(5) 20,928.95 89.07 152.52 7,712.46 7,641.66 -13,058.00 11,767.72 5,952,278.49 1,500,746.80 0.20 17,054.14 MWD+IFR-AK-CAZ-SC(5) 21,023.98 89.71 151.49 7,713.47 7,642.67 -13,141.91 11,812.32 5,952,193.71 1,500,789.70 1.28 17,149.17 MWD+IFR-AK-CAZ-SC(5) 21,119.93 89.49 152.36 7,714.14 7,643.34 -13,226.57 11,857.48 5,952,108.17 1,500,833.14 0.94 17,245.11 MWD+IFR-AK-CAZ-SC(5) 21,215.55 89.95 151.84 7,714.61 7,643.81 -13,311.07 11,902.22 5,952,022.78 1,500,876.17 0.73 17,340.73 MWD+IFR-AK-CAZ-SC(5) 21,311.03 90.02 151.75 7,714.63 7,643.83 -13,395.21 11,947.34 5,951,937.76 1,500,919.59 0.12 17,436.21 MWD+IFR-AK-CAZ-SC(5) 21,405.70 89.60 151.20 7,714.95 7,644.15 -13,478.39 11,992.55 5,951,853.69 1,500,963.11 0.73 17,530.87 MWD+IFR-AK-CAZ-SC(5) 21,500.90 89.32 151.15 7,715.84 7,645.04 -13,561.79 12,038.45 5,951,769.39 1,501,007.32 0.30 17,626.06 MWD+IFR-AK-CAZ-SC(5) 21,596.84 89.04 150.19 7,717.22 7,646.42 -13,645.42 12,085.44 5,951,684.83 1,501,052.61 1.04 17,721.96 MWD+IFR-AK-CAZ-SC(5) 21,692.60 89.19 150.68 7,718.70 7,647.90 -13,728.70 12,132.68 5,951,600.63 1,501,098.16 0.54 17,817.68 MWD+IFR-AK-CAZ-SC(5) 21,788.05 88.91 149.65 7,720.28 7,649.48 -13,811.49 12,180.16 5,951,516.91 1,501,143.96 1.12 17,913.06 MWD+IFR-AK-CAZ-SC(5) 21,883.98 88.99 152.03 7,722.04 7,651.24 -13,895.24 12,226.89 5,951,432.24 1,501,189.00 2.48 18,008.95 MWD+IFR-AK-CAZ-SC(5) 21,978.50 89.02 149.36 7,723.68 7,652.88 -13,977.65 12,273.15 5,951,348.92 1,501,233.58 2.82 18,103.42 MWD+IFR-AK-CAZ-SC(5) 22,073.22 88.95 150.24 7,725.36 7,654.56 -14,059.50 12,320.78 5,951,266.14 1,501,279.55 0.93 18,198.06 MWD+IFR-AK-CAZ-SC(5) 22,168.94 89.05 148.14 7,727.03 7,656.23 -14,141.69 12,369.80 5,951,182.98 1,501,326.90 2.20 18,293.64 MWD+IFR-AK-CAZ-SC(5) 22,264.29 89.33 146.88 7,728.37 7,657.57 -14,222.11 12,421.01 5,951,101.55 1,501,376.48 1.35 18,388.69 MWD+IFR-AK-CAZ-SC(5) 22,359.82 89.08 147.87 7,729.70 7,658.90 -14,302.56 12,472.51 5,951,020.09 1,501,426.34 1.07 18,483.90 MWD+IFR-AK-CAZ-SC(5) 22,453.96 89.12 150.03 7,731.18 7,660.38 -14,383.19 12,521.06 5,950,938.50 1,501,473.25 2.29 18,577.89 MWD+IFR-AK-CAZ-SC(5) 22,549.61 89.16 150.34 7,732.61 7,661.81 -14,466.17 12,568.61 5,950,854.58 1,501,519.12 0.33 18,673.48 MWD+IFR-AK-CAZ-SC(5) 22,645.17 88.26 149.56 7,734.77 7,663.97 -14,548.87 12,616.45 5,950,770.95 1,501,565.28 1.25 18,768.95 MWD+IFR-AK-CAZ-SC(5) 1/30/2017 1:54:17PM Page 8 COMPASS 5000.1 Build 74 i r SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9©70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production 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 22,739.93 87.49 149.30 7,738.28 7,667.48 -14,630.40 12,664.61 5,950,688.47 1,501,611.79 0.86 18,863.55 MWD+IFR-AK-CAZ-SC(5) 22,835.16 87.64 148.71 7,742.33 7,671.53 -14,711.96 12,713.60 5,950,605.95 1,501,659.13 0.64 18,958.56 MWD+IFR-AK-CAZ-SC(5) 22,930.94 87.88 151.06 7,746.07 7,675.27 -14,794.74 12,761.62 5,950,522.22 1,501,705.47 2.46 19,054.20 MWD+IFR-AK-CAZ-SC(5) 23,025.51 88.72 150.61 7,748.87 7,678.07 -14,877.28 12,807.69 5,950,438.78 1,501,749.86 1.01 19,148.70 MWD+IFR-AK-CAZ-SC(5) 23,120.96 88.43 152.85 7,751.25 7,680.45 -14,961.32 12,852.88 5,950,353.86 1,501,793.34 2.37 19,244.12 MWD+IFR-AK-CAZ-SC(5) 23,216.14 88.43 153.99 7,753.86 7,683.06 -15,046.40 12,895.45 5,950,267.93 1,501,834.19 1.20 19,339.23 MWD+IFR-AK-CAZ-SC(5) 23,310.89 89.09 154.24 7,755.91 7,685.11 -15,131.63 12,936.80 5,950,181.90 1,501,873.82 0.74 19,433.89 MWD+IFR-AK-CAZ-SC(5) 23,407.12 89.46 154.96 7,757.12 7,686.32 -15,218.55 12,978.08 5,950,094.18 1,501,913.33 0.84 19,530.02 MWD+IFR-AK-CAZ-SC(5) 23,502.84 89.91 155.52 7,757.65 7,686.85 -15,305.46 13,018.16 5,950,006.47 1,501,951.66 0.75 19,625.58 MWD+IFR-AK-CAZ-SC(5) 23,597.69 89.98 155.37 7,757.74 7,686.94 -15,391.74 13,057.58 5,949,919.43 1,501,989.32 0.17 19,720.26 MWD+IFR-AK-CAZ-SC(5) 23,693.15 89.39 155.46 7,758.27 7,687.47 -15,478.54 13,097.30 5,949,831.85 1,502,027.28 0.63 19,815.55 MWD+IFR-AK-CAZ-SC(5) 23,788.38 89.08 155.17 7,759.54 7,688.74 -15,565.06 13,137.06 5,949,744.56 1,502,065.30 0.45 19,910.61 MWD+IFR-AK-CAZ-SC(5) 23,883.67 89.19 154.68 7,760.98 7,690.18 -15,651.36 13,177.44 5,949,657.47 1,502,103.93 0.53 20,005.77 MWD+IFR-AK-CAZ-SC(5) 23,976.81 89.19 155.34 7,762.29 7,691.49 -15,735.77 13,216.79 5,949,572.29 1,502,141.56 0.71 20,098.77 MWD+IFR-AK-CAZ-SC(5) 24,074.20 89.15 155.36 7,763.70 7,692.90 -15,824.28 13,257.40 5,949,482.99 1,502,180.38 0.05 20,195.98 MWD+IFR-AK-CAZ-SC(5) 24,169.10 89.04 155.93 7,765.20 7,694.40 -15,910.72 13,296.53 5,949,395.78 1,502,217.76 0.61 20,290.68 MWD+IFR-AK-CAZ-SC(5) 24,264.29 89.47 156.58 7,766.44 7,695.64 -15,997.84 13,334.86 5,949,307.91 1,502,254.32 0.82 20,385.59 MWD+IFR-AK-CAZ-SC(5) 24,358.48 89.21 155.51 7,767.53 7,696.73 -16,083.91 13,373.10 5,949,221.09 1,502,290.82 1.17 20,479.54 MWD+IFR-AK-CAZ-SC(5) 24,454.31 89.92 155.09 7,768.25 7,697.45 -16,170.97 13,413.14 5,949,133.25 1,502,329.10 0.86 20,575.21 MWD+IFR-AK-CAZ-SC(5) 24,549.57 89.84 153.82 7,768.45 7,697.65 -16,256.92 13,454.22 5,949,046.50 1,502,368.43 1.34 20,670.38 MWD+IFR-AK-CAZ-SC(5) 24,644.46 89.84 152.45 7,768.72 7,697.92 -16,341.57 13,497.10 5,948,961.02 1,502,409.60 1.44 20,765.25 MWD+IFR-AK-CAZ-SC(5) 24,739.64 89.71 152.69 7,769.09 7,698.29 -16,426.04 13,540.94 5,948,875.68 1,502,451.73 0.29 20,860.42 MWD+IFR-AK-CAZ-SC(5) 24,834.39 88.65 152.68 7,770.45 7,699.65 -16,510.22 13,584.42 5,948,790.65 1,502,493.50 1.12 20,955.16 MWD+IFR-AK-CAZ-SC(5) 24,929.67 89.42 151.44 7,772.05 7,701.25 -16,594.38 13,629.05 5,948,705.62 1,502,536.42 1.53 21,050.42 MWD+IFR-AK-CAZ-SC(5) 25,025.67 88.23 150.89 7,774.02 7,703.22 -16,678.46 13,675.34 5,948,620.63 1,502,581.01 1.37 21,146.39 MWD+IFR-AK-CAZ-SC(5) 25,120.44 89.69 150.80 7,775.74 7,704.94 -16,761.20 13,721.50 5,948,536.98 1,502,625.49 1.54 21,241.12 MWD+IFR-AK-CAZ-SC(5) 25,215.48 89.14 150.36 7,776.71 7,705.91 -16,843.98 13,768.18 5,948,453.28 1,502,670.49 0.74 21,336.12 MWD+IFR-AK-CAZ-SC(5) 25,311.27 89.23 149.12 7,778.07 7,707.27 -16,926.71 13,816.45 5,948,369.60 1,502,717.08 1.30 21,431.83 MWD+IFR-AK-CAZ-SC(5) 25,407.05 88.88 150.99 7,779.65 7,708.85 -17,009.69 13,864.25 5,948,285.69 1,502,763.20 1.99 21,527.54 MWD+IFR-AK-CAZ-SC(5) 25,502.47 88.88 150.35 7,781.52 7,710.72 -17,092.86 13,910.98 5,948,201.60 1,502,808.24 0.67 21,622.91 MWD+IFR-AK-CAZ-SC(5) 25,599.03 89.05 149.69 7,783.26 7,712.46 -17,176.49 13,959.22 5,948,117.02 1,502,854.79 0.71 21,719.40 MWD+IFR-AK-CAZ-SC(5) 25,693.88 89.51 151.11 7,784.46 7,713.66 -17,258.95 14,006.07 5,948,033.64 1,502,899.96 1.57 21,814.20 MWD+IFR-AK-CAZ-SC(5) 25,789.07 89.29 150.65 7,785.45 7,714.65 -17,342.11 14,052.39 5,947,949.58 1,502,944.59 0.54 21,909.37 MWD+IFR-AK-CAZ-SC(5) 25,883.07 89.33 151.58 7,786.58 7,715.78 -17,424.40 14,097.79 5,947,866.39 1,502,988.33 0.99 22,003.35 MWD+IFR-AK-CAZ-SC(5) 25,977.58 89.15 151.55 7,787.84 7,717.04 -17,507.50 14,142.79 5,947,782.40 1,503,031.64 0.19 22,097.85 MWD+IFR-AK-CAZ-SC(5) 26,074.97 89.18 151.43 7,789.26 7,718.46 -17,593.08 14,189.27 5,947,695.92 1,503,076.38 0.13 22,195.22 MWD+IFR-AK-CAZ-SC(5) 26,169.53 89.71 149.84 7,790.17 7,719.37 -17,675.48 14,235.64 5,947,612.60 1,503,121.08 1.77 22,289.75 MWD+IFR-AK-CAZ-SC(5) 26,265.79 90.01 150.87 7,790.41 7,719.61 -17,759.14 14,283.25 5,947,528.01 1,503,166.99 1.11 22,385.97 MWD+IFR-AK-CAZ-SC(5) 26,360.86 89.94 151.82 7,790.45 7,719.65 -17,842.56 14,328.84 5,947,443.69 1,503,210.89 1.00 22,481.03 MWD+IFR-AK-CAZ-SC(5) 26,456.52 89.77 152.10 7,790.69 7,719.89 -17,926.99 14,373.81 5,947,358.38 1,503,254.14 0.34 22,576.69 MWD+IFR-AK-CAZ-SC(5) 1/30/2017 1:54:17PM Page 9 COMPASS 5000.1 Build 74 410 • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-18 Project: Western North Slope TVD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-18:33.9+36.9 @ 70.80usft(Doyon 19) Well: CD5-18 North Reference: True Wellbore: CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26 551.60 89.47 151.68 7,791.32 7,720.52 -18,010.86 14,418.60 5,947,273.64 1,503,297.24 0.54 22,671.77 MWD+IFR-AK-CAZ-SC(5) 26,646.29 88.39 150.05 7,793.09 7,722.29 -18,093.55 14,464.69 5,947,190.04 1,503,341.65 2.06 22,766.42 MWD+IFR-AK-CAZ-SC(5) 26,741.87 88.02 149.53 7,796.08 7,725.28 -18,176.11 14,512.76 5,947,106.54 1,503,388.05 0.67 22,861.88 MWD+IFR-AK-CAZ-SC(5) 26,836.93 87.95 149.95 7,799.43 7,728.63 -18,258.16 14,560.64 5,947,023.54 1,503,434.26 0.45 22,956.81 MWD+IFR-AK-CAZ-SC(5) 26,932.73 87.81 150.25 7,802.97 7,732.17 -18,341.15 14,608.36 5,946,939.61 1,503,480.29 0.35 23,052.49 MWD+IFR-AK-CAZ-SC(5) 26,983.52 87.85 150.06 7,804.89 7,734.09 -18,385.18 14,633.62 5,946,895.09 1,503,504.66 0.39 23,103.21 ) latarJ 4 1/2"x 6-3/4" 27,027.60 87.89 149.89 7,806.53 7,735.73 -18,423.31 14,655.66 5,946,856.52 1,503,525.93 0.39 23,147.24 MWD+IFR-AK-CAZ-SC(5) 27,089.00 87.89 149.89 7,808.79 7,737.99 -18,476.39 14,686.44 5,946,802.84 1,503,555.63 0.00 23,208.55 PROJECTED to TD 1/30/2017 1:54:17PM Page 10 COMPASS 5000.1 Build 74 • • N "0 M O v 0 ,- O v •a) 1 • N. O 4) v) 16 ,_ t C T = O O V � 41 O CO 4-' O w a -4...,. E 0 U c al CO C 0 t0N a) = ,, G) d v o > r=. c o rn n '= IQ �� >41, o d o v .� o0 1 ca c (6 0 o >+ z) c -c _a) c z E a- o 03 d N o N c v cn W U oc = 0. U `'_ tii y o >• o =cai _ `t- w 0 ) its (n >, •f- c a IB ••- N _ ; N d Y a� LL w >- � U) aO` U) � a. aooa 2 > asQ > w c 0 Y CO � c U) $ 0 a INV I) U pro Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Tuesday,January 24, 2017 12:32 PM To: Loepp,Victoria T(DOA) Subject: CD5-18(PTD 216-111)and CD5-99 (PTD 216-122) Frac Sundry Update Attachments: CD5-99 Slides,.pptx Follow Up Flag: Follow up Flag Status: Flagged Victoria, This email is to clarify implications stemming from the CD4-321 mechanical integrity event,which we previously notified you of on 1/18,particularly for the stimulations of CD5-99(PTD#216-122)and CD5-18(PTD#216-111). • CD4-321 passed tubing and IA drawdown tests on 1/22 after setting a tubing plug on 1/20. • CD4-321 is scheduled for a combination MIT-TxIA on"'1/24(and additional diagnostics as required)to confirm a downhole barrier. It failed a preliminary MIT-IA with crude freeze protect on 1/22/17. • On 1/14/17 the tubing and casing pack offs passed integrity tests, indicating a second tested barrier. • CD4-321 has a good primary cement job on the production casing based on the CBL,and a secondary cement job on the Qannik that went as planned. ConocoPhillips has completed an analysis of the proposed hydraulic fractures on CD5-99 and CD5-18 that shows these wells will have zonal isolation in the Alpine A Sand based on seismic,well and other subsurface information currently available and there is no reason to delay these stimulations based on the following: CD5-99 o CD5-99 is 1985'away from the CD4-321 Alpine A sand penetration (which has been P&A with cement), and 830'ND below CD4-321 directly above where it crosses CD5-99 as indicated in the attached PowerPoint. o Frac modelling shows a 90'frac height growth and 520'frac half-length, so ConocoPhillips is confident the frac will be confined to the Alpine Sands and will not grow through the confining shales into CD4- 321. o The identified faults within a'mile radius of the wellbore do not extend up through the confining interval based on seismic,well and other subsurface information. CD5-18 o CD5-18 is 1150'away from the CD4-321 Alpine A sand penetration(which has been P&A with cement)as indicated in the attached PowerPoint. o Frac modelling shows a 90'frac height growth and 520'frac half-length,so ConocoPhillips is confident the frac will be confined to the Alpine Sands and will not grow through the confining shales into CD4-321. o The identified faults within a%mile radius of the wellbore do not extend up through the confining interval based on seismic,well and other subsurface information. We wanted to be proactive in notifying the AOGCC of this change but would like to proceed with the stimulations that could start as early as 1/27, pending approvals. Please let me know if you have any questions or concerns. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office:(907)265-6342 1 • • Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Monday, February 06, 2017 6:29 PM To: Schwartz, Guy L(DOA) Cc: Loepp,Victoria T(DOA);Wallace,Chris D (DOA) Subject: Re: [EXTERNAL]RE:CD5-18(PTD 216-111, Sundry 317-025) Follow Up Flag: Follow up Flag Status: Flagged Guy, Thank you for reviewing these changes,the quick turnaround is greatly appreciated. Thanks, Hanna From:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Sent: Monday, February 6,2017 6:20 PM Subject: [EXTERNAL]RE: CD5-18(PTD 216-111,Sundry 317-025) To:Sylte, Hanna<hanna.sylte@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>,Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Hanna, You have approval to modify the tubing pressure test and IA hold pressure(and PRV setting) as outlined in the email below.As you mention the differential pressure requirement will still be satisfied at 110%of predicted max treating pressure with the proposed modifications. A Treesaver must be utilized to protect wellhead and production tree components. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From:Sylte, Hanna [mailto:Hanna.Sylte@conocophillips.com] Sent: Monday, February 06, 2017 4:43 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: FW:CD5-18(PTD 216-111,Sundry 317-025) 1 • • Guy, ^ Please review the updated frac pressures for CD5-18 listed below. We attempted to pressure test to 5,740 psi with the tree saver on and a plug in the XN without keys, but the plug did not hold.Slickline attempted to reset the plug with slip stops but were not successful due to the high deviation, so the decision was made to lower the pressure test to 5,000 psi without the tree saver on in order to avoid further delay on the frac.We were able to obtain a passing pressure test to 5,000 psi.A tree saver will still be run for the frac as originally planned. Similarly to what we did on CD5-99,we are planning to hold 2,682 psi on the annulus during the frac,with 500 psi held on the backside.This should still satisfy the requirement to test to 110%of the maximum anticipated pressure differential. Please let me know if you approve of this change or have any questions or concerns. AOGCC Required Previously Updated Pressures [all in psi] Submitted Pressures Maximum Predicted 7,400 7,225 Treating Pressure (MPTP) Annulus pressure during 2,182 2,682* frac Annulus PRV setpoint 2,282 2,782 during frac 7 5/8"Annulus pressure 2,400 2,400 test OA Pressure during frac 500 3 1/2"Tubing pressure 5,740 5,000 Test Nitrogen PRV 8,740 8,740 Highest pump trip 8,540 8,540 *Allowance of 2682 psi IA pressure during frac based on 2400 psi IA test- 10% + 500 psi in OA Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office:(907)265-6342 Mobile:(713)449-2197 From:Sylte, Hanna Sent: Monday, February 06, 2017 2:26 PM To: 'victoria.loeppCa@alaska.gov'<victoria.loepp@alaska.gov> Subject:CD5-18(PTD 216-111,Sundry 317-025) Victoria, 2 • • Due to operational and time constraints we were not able to pressure test the tubing on CD5-18(PTD 216-111,Sundry 317-025)to 5,740 psi as stated in the sundry application.We did obtain a passing MIT-T to 5,000 psi,and have adjusted the pressures accordingly.Similar to what we did on CD5-99,we are planning to hold 2,682 psi on the annulus during the frac,with 500 psi held on the backside.This should still satisfy the requirement to test to 110%of the maximum anticipated pressure differential. Please see the updated pressures in the table below and let me know if you approve this change or have any questions or concerns. AOGCC Required Previously Updated Pressures [all in psi] Submitted Pressures Maximum Predicted 7,400 7,225 Treating Pressure (MPTP) Annulus pressure during 2,182 2,682* frac Annulus PRV setpoint 2,282 2,782 during frac 7 5/8"Annulus pressure 2,400 2,400 test OA Pressure during frac 500 3 1/2"Tubing pressure 5,740 5,000 Test Nitrogen PRV 8,740 8,740 Highest pump trip 8,540 8,540 *Allowance of 2682 psi IA pressure during frac based on 2400 psi IA test- 10% + 500 psi in OA. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office:(907)265-6342 Mobile:(713)449-2197 3 • . E. 5958000 5956000 5954000 5952000 5950000 5948000 N - N _ —a 0 C4 itnt en o ict In CDC‘-;9 o 0 V - a r7 rq LO y - . 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Q.) c < > co = 25 Q.) < cu 0 •— fN • • a :'-f-- c, 0 0 c 0 � u a) a) C Q d C LP) N 0 v U Z3 - 2 c0 N I— m 4, 00 U (c „R O v J ma b66% SCJ 442, a 49//j• 4 140 J s CU J cp O -0 NSI, a� as 3 a,O N — O C y-- C N •C ° _� U C U LA▪ O N I, CU v +r u m o c Q U 0 / N Y CO v 3 m = C m 'n 0 Q •Qcu QC> = Y 2 Q Q H m • • pTO 216 -11) Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Tuesday,January 10, 2017 10:09 AM To: Loepp,Victoria T(DOA) Cc: Sylte, Hanna Subject: CRU CD5-18 (PTD 216-111) Follow Up Flag: Follow up Flag Status: Flagged Victoria, We have just finished drilling the CRU CD5-18L1(PTD 216-112)Alpine C lateral and will commence completing the well- CD5-18(PTD 216-111). As the CD5-18 will be hydraulically fractured, I wanted confirm that you have received my 2 emails on 12/29/2016 containing the Sonic and SCMT cement evaluation logs.Schlumberger had interpreted and ConocoPhillips agree with the top of cement at 11,350ft MD.We intend to move forward with completing the well as described in the approved PTD 216-111 and 216-112. Per the permit,can you please confirm your prior receipt and review of the 2 previous CBL emails. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart(a7conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 1 From: Jason Burt To: Earhart,Will C; Erik Sterk Cc: Stephen La up Subject: [EXTERNAL]CD5-18 Top of Cement Analysis Date: Monday,December 26,2016 10:54:23 PM Schlumberger-Private Schlumberger-Private Hi Will, I have processed the top of cement analysis for the CD5-18 well. I have identified a top of cement at 11,350 ft MD. I have included a copy of the log in this email and uploaded the logs and data to InterACT. It is located in the following folder. Top > CPAI > Colville River Unit > CD5-18 > Sonic Top of Cement Top > CPA= > Colville River Unit > CD5-18 > Sonic Top of Cement Please let me know if there are any questions or comments. Regards, Jason Jason Burt Ph.D. Schlumberger p sls Senior Petrophysicist& Well Placement Engineer Office: (907)273-1748 Cell: (907)440-9220 The information and/or data contained in this communication is confidential and intended solely for the individual or entity addressed herein.If you received this email in error,please delete and contact the sender. Schlumberger does not guarantee results of its services,realizing the same are opinions based on inferences from measurements and testing. Customer takes full responsibility for use of any deliverables,data,interpretations,or recommendations provided by Schlumberger. No entity may publish or display information or data provided by Schlumberger to another party, nor may any entity use Schlumberger's name or trademark(s)without prior written authorization. �_v m 0 p� 1`" * n C/:1 z _ a — c i rn M C2 c cn o co CD = 0D n 71 o 0 - 0 0 Cn tr . . Q ke W N a 0 CD 5 n 3 = '_ o co msu c-6- .— c-) a 5 ,.,,u) E _0;-, a4 gi 2 DWS. ;ro C/3 CD uu CD LP pm ri■ Co o - tD c,a F,.., cn 0 v mo � � 0 o cco 5' 00 00 o cD - O n o cD 1 o CC/2 * Oin 0o N y T Po - 3 V O el ro y o 0 ~� m z0 0co o N n r E g = = w F D w -, m rt O 7 FOLD HERE: The well rdie,Iec,E•on and borehde refuu ice data werefurished by the astanee Any irterpretatia,research,analysis,data,resrlts,estimates,or re crrmanda6m furished with the services a-otherwise c miinceted by Sdiurbegerb the asthmer at ary time in canedicn with the services are apiricns based ai defences frau rreasucmants,empirical rdatic ship,axis assurpions;with,irierenoes,empirical redatiaistips adcr assure ons are rat irfallide aid with respect in which ptfessicr s in the industry nay differ.Acarrinjy,Schlarbager cant and does notwarat the aoaxacy,earecfi�ess,a earpleterress claysuch irtsrprdation,researh,analysis,dela restlls,estirrs,a ramrmendaion the astcmer adaonrledges that itis aooeping the services"as is,"that Schulte-gar rrekes no repr ep a-wa!aty,express a.implied,cf ary kind cr desaipten in respect thereto,aid that such services ae delivered with the explicit uiderstadng ad ageerrent that aiy a liai taken used an the service;;received shall beat its own risk aid responsibility,ad no dam shall be made aclainst Sdiurt eger as a consequence thereof. Svc.Order#: Inthrpretation Center: Analyst:J Bu rt 2 Process Date: 26 Dec 2016 Location:AKA Techlog Vers: 2015.3 Remarks: 4 i i `! a f 1 IL' r i,: -:- ,'''.1-,1','.,' L Iis f 7 , 1 t. ,r r 1 . a 0 1 i , 1,, iii-1-11111i.11 1111.111 ' MM♦ 1.111111111111 tt - MIMI 41 111 Mill1 11 r- ,1 ih',c1 L Pil II s ` 1111 *11 71 0 1i 1 N �ltil,��l' IMO Imill r 1 ,,, + FOU111 lig 141 F... " �� 1111I it ,, C- dl.�� ,li,'ll` 1MM F;.1 1 I. ter ♦ Pi�' r EMM! . I�I i� I mil mg,,. PO nut. 1MMM1 1 I i t 11101 , O : ii 14. iiii t c'!!mo ':lMIMM ,� 3 IIINION ' Calf 1'1' --- r .� )t it! III 71111111641111 11 ', i :i : 11„1,„1 t ' 11 olioF►' ,, 11411001 • i I I -- ,,, b I - , . „,-,'L I ; , t ' 110 Et t j -152 1 0�- ( I _� _. - r _._ . i I 1 1 - r ilkiiii- 1 1. i . I i Ai ^e. % f( ' ( �'' -� ' ' (1{1 L• I I Ci 4 { t ": i ------_,\AAq kivvvv, -15300 �. 1 —NW-AV - ''''''',':'';'' II I ' '4:- ' 1, timm— I ------0immiv\---v, 4 • - _ .. ;.. .. . .. • 4 i - ' - r i (6 t s ' . .. I °. ---'------'--1Alk,AftWV\I\At'N/‘" Casing o , i M dj- It)) (coo CO co o 000000000 `ST Projection V CSID_PREVEIWMir 5 in 8 `�'iii, , -115.94 MI CSOD_PREVEIW SPR_MH_FA_R_1 WF_FILT_MH_2 - R 1 WFA_MHT- R 1 5 in 8 0 us 3000 0 us 3000 DTSH MH FAR 1 . ASI\. E eferenc - - - - us 3C,, (ft) DTCO MH_FA_R_1 Casing Amplitude CASING_TW_E 2 1:480 I _ -20 unitless 100 u • 11/ Company: ConocoPhillips Alaska, Inc. Schlumberger Well: CD5-18 Field: Colville River Unit State: Alaska SonicScope Top of Cement Evaluation CemCAT v1.5 Schlumberger Cementing )ob eport Well CDS 18 Client Conoco Phillips Field Alpine SIR No. DNWZ-00015 Engineer Todd Jagger Job Type 2nd stage Intermediate Country United States Job Date 12-17-2016 Time Pressure Rate Density WHP Messages 03:54:07 PJSM Batch Tub of Spacer 04:04:00 Start Spacer 04:14:00 End Spacer Reset Total,Vol=43.11 bbl Batch Tub Of Cement 04:24:00 -- Start Cement Slurry 04:34:00 04:44:00 ! Reset Total,Vol=57.62 bbl End Cement Slurry Load Plug Start water behind 04:54:00 End water Behind Reset Total,Vol=10.17 bbl 05:04:00 05:14:00 05:24:00 05:34:00 05:44:00 05:54:00 .J 06:06:28 Bump plug @ 2815 strokes Close Stage Tool hh:mm:ss 0.00 1000 2000 3000 4000 5000 0.00 2.0 4.0 0.0 60 10.0 5.0 0.0 13.0 17.0 2L0 25.0 0.00 1000 2000 3000 4000 5000 vmnuuaeaka PSI 8/M LB/G PSI 12/17/2016 13:54:32 • Jobport CemCAT v1.5 Cementingte Schlumberger Well CD5-18 Client Conoco Phillips Field Alpine SIR No. DNWZ-00015 Engineer Todd Jaggers Job Type 7.625'Int. isr stage Country United States Job Date 12-16-2016 Time Pressure Rate Density WHP Messages wanmaaxsea 22:56:32 PJSM 1 Flood Lines Shut in for PT PT surface Lines 23:17:00 —Jl Bld off PT Mix eeTub of Spacer Reset Total,Vol=2.10 bbl Start Spacer •.Z A. 23:37:00 ( End Spacer Mix up tub Cement 7 I Reset Total,Vol=43.65 bbl Start Cement Slurry 23:57:00 Shut Down Casing Head Leaking Resume Pumping 00:17:00 00:37:00 End Cement Slurry a Reset Total,Vol=215.67 bbl Drop Top Plug Start water behind Reset Total,Vol=10.32 bbl 00:57:00 End Water behind Rig to displace 4 01:17:00 • 01:37:00 i 01:57:00 02:17:00 02:37:00 • 02:57:00 \` 03:07:52 1 Reset Total,Vol=53.95 bbl Bump Plug @ 6846 strokes Floats hold hh:mm:ss 0.00 1000 2000 3000 1000 5000 0.00 2.0 4.0 6.0 0.0 10.0 0.0 0.0 13.0 17.0 21.0 25.0 0.00 1000 2000 3000 4000 1000 unrn0160x01.0z PSI Wm LB/G PSI 12/17/2016 13:45:04 • • e 0 01111 Cement Detail Report CD5-18 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 11/30/2016 20:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/16/2016 22:45 12/17/2016 05:30 CD5-18 Comment Cemented two stage job with full returns.40 bbl Mud Push ahead of each stage. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement intermediate, 12,796.0 15,263.0 Yes Yes Yes Cement 500'above Kup C Q Pump Init(bbl/m...0 Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 8 7 750.0 1,300.0 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 12,796.0 15,263.0 1,036 G 215.7 Yield(ft'Isack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 128.0 6.00 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 Isolate Qannik,500' 5,650.0 6,350.0 Yes Yes No Cement above 0 Pump Init(bbl/m...Q Pump Final(bbl/...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 8 7 360.0 1,500.0 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 5,650.0 6,350.0 276 G 57.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 143.0 4.75 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 Page 1/1 Report Printed: 12/29/2016 • • Loepp. Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Thursday, December 29,2016 12:08 PM To: Loepp,Victoria T(DOA) Subject: CRU CD5-18 (PTD 216-111):Intermediate Cement Update- Email lof 2 Attachments: CD5-18 WV Intermediate Cement Job Report.pdf;CD5-18 STG 1 Plot Report Configuration.pdf;CD5-18 STG 2 Plot Report Configuration.pdf;COP CD5-18 Top of Cement Analysis Scale480.pdf, [EXTERNAL]CD5-18 Top of Cement Analysis.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached please find the following information for CRU CD5-18(PTD 216-111)for the intermediate casing cement jobs: 1. Wellview Job Report 2. Schlumberger Job Log 3. Schlumberger SonicScope LWD Top of Cement evaluation 4. Schlumberger SonicScope TOC interpretation email 5. Schlumberger SCMT CBL log(sent in second email do to file size) Both the first and second stage cement jobs on the intermediate casing went as planned. Both were performed at planned rate,with full returns and with no losses.All plugs bumped and floats held as intended.On 12/20/16,a successful FIT of the intermediate casing shoe was performed to 12.5ppge. Please let me know if you'd like me to provide any further data. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhartconocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 1 e— e— • IlL e—© o4„W ~ T e cn r O r r r M X r o LID =1 _1A� ff " � 6 m _. 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M M M _ O O O O i v O O O +' 0 C) 4 c LC) U) v) 0. u C) 1:13 e4 Ln .E, •u co a) G �i cc c WO le C CO U 4-, Q -"" Q ,� m 3 a. 9 2 no D o r ."_ E v rn E2 Ln 6ro c a a O N V Cl V E Z N Ya c _ } tt0 r u i U (a r ar c6 OND Lb 4/ it a -c-1- :-(t- 2« — j/2, Loepp, Victoria T (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, September 30, 2016 10:00 AM To: Loepp,Victoria T(DOA); Earhart,Will C Subject: RE:CRU CD5-18 (PTD 216-111)and CRU CD5-18L1 (PTD 216-112) Follow Up Flag: Follow up Flag Status: Flagged Will, Thank you for the notification concerning the errors in Range for CD5-18 and CD5-18L1, and northing and easting for CD5-18's total depth. The errors have been corrected in AOGCC's database and no further action is required by ConocoPhillips. A copy of your email will be placed in the well history file. Thank you, Patricia From: Loepp,Victoria T(DOA) Sent:Thursday,September 29,2016 5:19 PM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: Fwd:CRU CD5-18(PTD 216-111)and CRU CD5-18L1(PTD 216-112) Please advise. Sent from my iPhone Begin forwarded message: From: "Earhart,Will C"<William.C.Earhart@conocophillips.com> Date:September 29,2016 at 5:11:04 PM AKDT To:"Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov> Subject:CRU CD5-18(PTD 216-111)and CRU CD5-18L1(PTD 216-112) Victoria, It was just brought to my attention that I had made errors in the TD location on both the CRU CD5-18 (PTD 216-111)and CRU CD5-18L1 (PTD 216-112) PTDs. Both were listed as being in R3E; however, both are in R4E.Can you please advise me the proper way to rectify this error in your records? In PTD 216-112,the NAD27 northing and easting at total depth are listed corrected. In PTD 216-111,the NAD 27 northing and easting are in error as well and should be: CRU CD5-18(PTD 216-111)Total Depth NAD27 Northing: 5,947,204 Easting: 363,471 1 • • All other information is correct. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.EarhartCa�conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 2 MEW OF rit • w I1/7, THE STATE Alaska Oil and Gas �,,,_� o f T c Conservation Commission , _= - ALAS 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of A S�Q` Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CRU CD5-18 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-111 Surface Location: 391' FNL, 2766' FEL, SEC. 18, T11N, R4E, UM Bottomhole Location: 2896' FNL, 4046' FEL, SEC. 34, Ti 1N, R3E, 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, / Cathy '. Foerster Chair DATED this 24 day of September, 2016. hUit1Vti) STATE OF ALASKA SEP 0 6 2016 AI4PA OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL AOGC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill 0• Lateral ❑ Stratigraphic Test ❑ Development-Oil 0 • Service- Winj ❑ Single Zone 0 •• Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 - Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. • Bond No. 59-52-180 - CRU CD5-18 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 27000 • TVD: . 7730 Colville River Unit/ • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Alpine Pool Surface: 391'FNL,2766' FEL,Sec.18,T11N,R4E,UM ' ASRC-NPR2, NPR4,ASRC-AA092344 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2926'FNL,4355'FEL,Sec.21,T11N, R4E,UM 932128,932669,340757 10/6/2016 Total Depth: �{ 9.Acres in Property: 14.Distance to Nearest Property: 2896'FNL,4046'FEL,Sec.34,T11N, R31E,UM 8838,5032,3122 • 267'from ADL387209 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 70.2, 15.Distance to Nearest Well Open Surface: x- 349212 y- 5965824 Zone-4 • GL Elevation above MSL(ft): 33.9+ to Same Pool: 3060'from CD5-99 16.Deviated wells: Kickoff depth: 300 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89.4 degrees • Downhole: 3599 Surface: 2769, 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 B Welded 80 36 36 116 116 10 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2343 36 36 2379 2185 1018 sx 11.0 ppg,271 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 15031 36 36 15067 7609 923 sx 15.8 ppg G 6-3/4" 4-1/2" 12.6 L-80 TXP 12080 14920 7494 27000 7730 Uncemented liner w/frac ports 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 ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date °�1/,..,._......-- 9/6/2016 22.I hereby certify that the foregoing is true and the procedure approved herein will not Will Earhart 265-1077 be deviated from without prior written approval. Contact William.C.Earhart@cop.com Email Printed Name Chip Alvord Title Drilling Manager for) -,f1 Signature _ Q Phone 265-6120 Date V "" Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: 0.1G ' /` l 50-1o3_. „.o'5 Q--00-ob Date: ql a'1i Vrequirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 17{, Other: San 7`e6 f f0 3 57.2O p 5 r Samples req'd: Yes No Mud log req'd:Yes No r h v a rp r t Ve .i tt�' t/5? to 2-560 psi H2S measures: Yes V No r_., Directional svy req'd:Yes 'No 11 0/"I/Cr tc/� I,,/A 1,t/C� q_k'a VI'fir Spaci> exception req'd: Yes ❑ No Inclination-only svy req'd:Yes r.__. No 72-r �e _AA 2- ' 036.0'1)(2) �� �� Post initial injection MIT req'd:Yes ❑ No �� l er'Gratd+'�'CCJ 1-0 20AA-C 2 2g;( t (/(/A 1 V l ."fit "y i� 1' ,7-%t `% ' t--9 � 0 1 I :`' p ea C tC C �` -toi allow 'ham , ' P + r 5gv)d Kir ov to �b e /o I I,e �' , �s'+, CC • fje �dGf��G� rC vl'rYcl for rr,TCr,h-r11 c�Cvw-cv>fcva � . � ✓icwwj 1� � C L a NC,r So v3 j 4 APPROVED BY Approved by: ( 9"- COMMISSIONER THE COMMISSION Date:4 ,..-2/....0. ,fill I i I( VT1- �Vz a 1 g,R� td Submit Form and Form 10-401(Revise 11 015) h it/� i nths from the date of approval(20 AAC 25.005(g)) Attachmentss in Duplicate • ConocoPhillips Alaska,Inc. Post Office Box 100360 1111'7' Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 September 6,2016 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 SEP 0 6 2016 Re:Application for Permit to Drill CRU CD5-18 AOGCC Dear Sir or Madam: 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 10/6/16. CRU CD5-18 is planned to be an Alpine A and C dual lateral producer,with the Alpine C lateral covered in the CD5-18L1 PTD. The 13-1/2"surface hole will TD above the C-30 sand and then 10-3/4"casing will be set and cemented to surface.The intermediate section will be drilled with a 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 suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak-off test. The 6-3/4"production section will then be horizontally drilled and completed as a producer in the Alpine A reservoir. This lateral will be completed with a 4-1/2"solid liner with frac ports across the productive zone. A second lateral, CD5-18L1,will then be drilled in the Alpine C sand. The L1 lateral and upper completion is covered in the CRU CD5-18L1 PTD application. A waiver is requested to set the Alpine A Sand production packer within 100' of the Alpine C sand window as per 20 AAC 25.283 (c). The prodution packer will be—60' below the Alpine C Sand window. It is the intention of ConocoPhillips to hydruallically fracture the CD5-18 Alpine A sand at a later date. 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 Will Earhart at 265-1077 (William.C.Earhart(/cop.com)or Chip Alvord at 265-6120. Sincere cc: CD5-18 Well File/Ann Haggerty-Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Will Earhart Jason McLennan ATO 1790 Drilling Engineer Lanston Chin Kuukpik Corp • Applicr Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 CD5-18 Application for Permit to Drill Document Drilling &Wells ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (I)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25005 (c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of20AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 (Requirements of 20 AAC 25.005 (c)(14)) 9 15. Attachments 10 Attachment 1 Cement Summary 10 CD5-18 APD Page 1 of 15 Printed:6-Sep-16 • Applic.or Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 Attachment 2 Drilling Hazards Summary 10 Attachment 3 Completion Schematic 10 Attachment 4 Directional Plan 10 CD5-18 APD Page 2 of 15 Printed:6-Sep-16 Applic or Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 1. Well Name (Requirements of 20 AAC 25.005(0) The well for which this application is submitted will be designated as CRU CD5-18. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 391'FNL,2766' FEL, Sec. 18,T11N,R4E,UM NAD 1927 RKB Elevation 70.2'AMSL Northings: 5,965,824 Eastings: 349,212 Pad Elevation 33.9'AMSL Top of Productive Horizon(Heel) 2926'FNL,4355'FEL, Sec.21,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 15,067' Northings: 5,957,836 Total Vertical Depth, RKB: 7,609' Eastings: 358,054 Total Vertical Depth, SS: 7,539' Total Depth (Toe) 2896'FNL,4046'FEL, Sec.34,T11N,R3E,UM NAD 1927 Measured Depth, RKB: 27,000' Northings: 5,91;61 66 S�jy 7� act{ Total Vertical Depth, RKB: 7,730' Eastings: 3497-5-14 .3(0'3I y Total Vertical Depth, SS: 7,660' 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. CD5-18 APD Page 3 of 15 Printed:6-Sep-16 • Applica or Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 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) 20 115/ 115 10.9 52 54 til �s i9°510.75 2,379/ 2,185 14.5 977 1 429 , 7.625 15,067/7,609 12.5 3,599 2,769 4.5 27,000/7,730 12.5 3,542 n a y V PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) 3V61/4 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 x D) 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 115=54 psi OR ASP=FPP-(0.1 x D) =977-(0.1 x 2185')=759 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 2185' = 1429 psi OR ASP=FPP-(0.1 x D) =3599-(0.1 x 7609')=2838 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 7701 =4236 psi OR ASP=FPP-(0.1 x D) =3542-(0.1 x 7730')=2769 psi (B)data on potential gas zones; CD5-18 APD Page 4 of 15 Printed:6-Sep-16 • Applica•or Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 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 Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) Siz'� (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 80 36/36 115/115 Previously Installed HYD Cement to Surface with 10-3/4 13.5 45.5 L-80 563 X 2,379 36/36 2,379/2,185 1018 sx DeepCrete Lead 11.0 ppg, BTCM 271 sx Class G Tail Slurry 15.8 ppg 9.875 HYD 7-5/8 x11 29.7 L-80 563 X 15,031 36/36 15,067/7,609 923 sx Class G at 15.8 ppg BTCM 4-1/2 6.75 12.6 L-80 TXP 12,080 14,920/7,598 27,000/7,730 N/A—uncemented liner with frac sleeves 7. Diverter System Information (Requirements o f 20 AAC 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, sixteen penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. CD5-18 APD Page 5 of 15 Printed:6-Sep-16 . Applicator Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 Casing Size in. 10.75 7.625 4.5 Density PPG 9.0—9.8 9.6— 11.1 9.2 PV cP ALAP ALAP 15-22 YP lb./100 ft2 30-50 20- 26 10 - 15 Initial Gels Ib./100 ft2 50 8-15 9-12 10 Minute Gels Ib./100 ft2 60 <20 12-18 API Fluid Loss cc/30 min. N.C.— 10.0 <10 <10 HPHT Fluid Loss cc/30 min. n/a <10 <5 pH 11.0 9.5— 10.0 N/A Surface Hole: A mixed-metal oxide fresh water drilling fluid(Drilplex)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 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 10.8 ppg before pulling out of the hole. Note: Managed Pressure Drilling(MPD)will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with an oil based mud drill-in fluid(VersaPro)weighted to 9.2 ppg utilizing a 80:20 Oil Water Ratio and calcium carbonate. LVT-200 will be used as the base oil and CaC12 brine, 33%by weight for the water phase. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-18 APD Page 6 of 15 Printed:6-Sep-16 • Loepp, Victoria T (DOA) From: Njoku,Johnson <Johnson.Njoku@conocophillips.com> Sent: Tuesday, September 06,2016 4:20 PM To: Loepp,Victoria T (DOA) Cc: Quick, Michael J (DOA);Schwartz,Guy L(DOA);Wallace, Chris D (DOA); Lee, David L; Kanady, Randall B Subject: RE: Cement Evaluation: Use of LWD sonic logs Follow Up Flag: Follow up Flag Status: Flagged Victoria, You probably have seen the note from Will Earhart regarding our plans for CBL and Sonic LWD comparison. We've made some design changes to CD5-99 and should be able to run both logs on the well, as well as on CD5-18 which is the next well on the schedule. 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: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,August 30,2016 3:29 PM To: Njoku,Johnson<Johnson.Nioku@conocophillips.com> Cc:Quick, Michael J (DOA)<michael.quick@alaska.gov>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>;Wallace, Chris D(DOA)<chris.wallace@alaska.gov>; Lee, David L<David.L.Lee@conocophillips.com> Subject: [EXTERNAL]RE:Cement Evaluation: Use of LWD sonic logs Johnson, I see Randy is out of the office. Please route these conditions to the appropriate individuals. We expect this information to be disseminated within CPAI drilling groups. In addition,we need to know which two upcoming wells in Kuparuk or Coville that the log comparison will be run in. Thanx, Victoria From: Loepp,Victoria T(DOA) Sent:Tuesday, August 30, 2016 3:20 PM To: Kanady, Randall B(Randall.B.Kanady@conocophillips.com) Cc: Quick, Michael J (DOA); Schwartz, Guy L(DOA); Wallace, Chris D (DOA); Njoku, Johnson (Johnson.Njoku@conocophillips.com); david.l.lee@conocophillips.com Subject: Cement Evaluation: Use of LWD sonic logs Randy, 1 • AOGCC will accept the use of LWD sonic logs to meet AOGCC regulations for cem nt evaluation logs for wells that will be fracture stimulated and for injection wells provided the following conditions are met: 1. The Permit to Drill application must specify whether the well will be an injection well or whether the well will be fracture stimulated. 2. CPAI must provide a minimum of two additional comparisons of the LWD sonic log versus the e-line cement evaluation log on the next two wells. Depending on the comparison,the AOGCC may accept the LWD sonic log to satisfy the requirement for cement evaluation under AOGCC regulations. 3. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. 4. LWD sonic logs must show free pipe and Top of Cement,just as the e-line log does. 5. CPAI will provide a cement job summary report along with the cement log evaluation to the AOGCC when they become available. 6. If the LWD sonic log type changes in the future,the new logs will be subject to a new review and approval by the AOGCC. 7. These conditions may be revised based new information. Based on these conditions, please propose the next wells that the comparison outlined in (2) above will be made. In addition,these conditions must be disseminated appropriately within your organization so that future PTDs are prepared to meet these conditions. 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 a(�,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.Loepp@alaska.gov 2 • lam%7 Z-1G — JI / • Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Tuesday,September 06, 2016 2:34 PM To: Loepp,Victoria T(DOA) Cc: Bettis, Patricia K(DOA); Njoku,Johnson Subject: CRU CD5-18 PTD Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the discussion earlier on mutli-lateral well PTD applications. I've completed the CRU CD5-18 PTDs and you should be seeing them later today. As you will note in the PTD,we intend to repeat the Sonic vs CBL(SCMT)cement evaluation comparison on that well per the AOGCC's request. Hopefully with the comparison data on 3 wells(CD5-06,CD5-99,CD5-18)we will all feel confident with the Schlumberger Sonicscope for TOC evaluation moving forward. I will be out of the office without any communication September 9-19. If you all have any questions on the PTDs during that time, please contact David Lee 263-3741. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 1 ! ! Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Tuesday, September 06,2016 2:34 PM To: Loepp,Victoria T(DOA) Cc: Bettis, Patricia K(DOA); Njoku,Johnson Subject: CRU CD5-18 PTD Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the discussion earlier on mutli-lateral well PTD applications. I've completed the CRU CD5-18 PTDs and you should be seeing them later today. As you will note in the PTD,we intend to repeat the Sonic vs CBL(SCMT)cement evaluation comparison on that well per the AOGCC's request. Hopefully with the comparison data on 3 wells(CD5-06,CD5-99,CD5-18)we will all feel confident with the Schlumberger Sonicscope for TOC evaluation moving forward. I will be out of the office without any communication September 9-19. If you all have any questions on the PTDs during that time, please contact David Lee 263-3741. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart(a�conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 1 • Applicator Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20AAC25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto CD5-18. 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(24 hr.AOGCC notice). 7. Pick up and run in hole with 9-7/8"x 11"drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3500 psi for 30 minutes. 9. Drill out 20' of new hole and perform LOT.Maximum LOT to 18.0 ppg.Minimum LOT required to drill ahead is 14.0 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). ✓ 11. Change out upper pipe rams to 7-5/8"solid bodies and test same to 3,500 psi. 12. Run 7-5/8"casing and cement to 500' above hydrocarbon bearing zones(cementing schematic attached). 13. Change upper pipe rams to 3-1/2"x 6"VBRs. 14. Test BOPE to 250 psi low/3,500 psi high(24 hr.AOGCC notice). ✓ 15. Pick up and run in hole with 6-3/4"drilling BHA. a. Evaluate TOC via sonic LWD tool while running in hole. 16. Chart casing pressure test to 3500 psi for 30 minutes. 17. Drill out shoe track and 20 feet of new formation.Perform FIT to of 12.5 ppg EMW.Minimum required leak- off value is 11.0 ppg EMW. 18. Drill 6-3/4"hole to section TD(LWD Program: GR/RES). 19. Pull out of hole with drilling BHA. CD5-18 APD Page 7 of 15 Printed:6-Sep-16 • Applicat•r Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 20. Run in hole with 4.5"Alpine A sand lower completion(uncemented liner with frac sleeves)including memory SCMT tool. 21. Set liner hanger and release from liner. Set liner top packer. 22. Pull out of hole evaluating intermediate cement job with memory SCMT tool. 23. End PTD for CD5-18 and begin PTD for CD5-18L1. CD5-18 APD Page 8 of 15 Printed:6-Sep-16 • Applicalpor Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 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 CD5-18 will be injected into a permitted surface casing x production casing annulus on CD5. ,/ The CD5-18 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 and Kuparuk sand based on pre-drill interpretations.There will be 500' of cement placed above the top of the Kuparuk reservoir. Once CD5-18 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) * (2,185')+ 1,500 psi =2863 psi Pore Pressure =977 psi Therefore Differential=2863—977= 1886 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/BTCM 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563/BTCM 4790 psi 4071 psi 6890 psi 5856 psi CD5-18 APD Page 9 of 15 Printed:6-Sep-16 • Applicalir Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-18 APD Page 10 of 15 Printed:6-Sep-16 • Applica•or Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 Attachment 1 —Cement Summary CD5-18 Cementing Program: CD5-18_wp6 Schematic L 20"94#H-40 Welded Conductor to 115' 10-3/4"45.5#L-80 HYD563/BTCM 2,379' MD/2,185'TVD @ 46°inc. 9-7/8"x 11" Hole Top of Cement 12,821' MD/7,081'TVD Kuparuk C 13,321' MD/7,304'TVD Alpine C 14,043,' MD/7,509'TVD 7-5/8"29.7 L-80 HYD563 X BTCM Casing 15,067' MD/7,609'TVD @ 87° Alpine A i 15,067' MD/7,609'TVD 6-3/4" Hole 27,000' MD/7,730 @ 89° CD5-18 APD Page 11 of 15 Printed:6-Sep-16 • Applicalikr Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 10.75" Surface Casing run to 2,379' MD/2,185'TVD Cement from 2379' MD to 1879'(500' of tail)with Class G+Adds. @ 15.8 PPG, and from 1879'to surface with 11.0 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost (1344' MD),zero excess in 20"conductor. Lead slurry from 1,879'MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (115'—36') X 1.3645 ft3/ft X 1.0 (0%excess) = 108 ft3 Permafrost to Conductor (1,344'— 115') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,565 ft3 Top of Tail to Permafrost (1,879'— 1,344')X 0.3637 ft3/ft X 1.5 (50%excess) = 292 ft3 Total Volume = 108 + 1,565 + 292 = 1,965 ft3=> 1018 sx of 11.0 ppg DeepCrete @ 1.93 ft3/sk Tail slurry from 2,379'MD to 1,879'MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,379'—1,879')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 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8%$002 accelerator @ 1.17 ft3/sk 7.625"Intermediate Casing run to 15,067'MD/7,609' TVD Top of slurry is designed to be at 12,821' MD,which is 500' above the Kuparuk C.Assume 40%excess annular volume. *11"Under reamer is 110' above the 9-7/8"bit. Tail slurry from 15,067'MD to 12,821'MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8"Hole (15,067'— 14,957')X 0.2148 ft3/ft X 1.40 (40%excess) = 33 ft3 11"Hole to Top of Cement (34 ,957'— 12,821')X 0.3428 ft3/ft X 1.40 (40%excess) = 1025 ft Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) = 21 ft3 Total Volume = 33+ 1025 + 21 = 1079 ft3 => 923 sx of 15.8 ppg Class G + 0.2% D046 antifoamer,0.3% D065 dispersant and 0.8%S002 accelerator @ 1.17 ft3/sk CD5-18 APD Page 12 of 15 Printed:6-Sep-16 . Applicaler Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 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 H25 drills,detection systems, alarms, standard well control practices, mud scavengers 6-3/4"Open Hole 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 CD5-18 APD Page 13 of 15 Printed:6-Sep-16 • Applicalpor Permit to Drill,Well CRU CD5-18 Saved:6-Sep-16 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/Miluveach and instability in the intermediate 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. CD5-18 APD Page 14 of 15 Printed:6-Sep-16 • Applicallkir Permit to Drill,Well CRU CD5-18 Saved: 6-Sep-16 Attachment 3-Completion Schematic (includes Alpine C lateral, as detailed in CD5-18L1 PTD) CD5 - 18 Alpine A/C Dual Lateral Producer Proposed Schematic 20"94#H-40 Welded Upper Completion: Conductor to 115'MD 1)3-'/z"9.3#/ft eue8rd 2)Shallow nipple profile 2.812"ID 3)3-1/2"x 1"Camco KBMG GLM(xx°)w/DCK2 pinned for 2500 psi casing to tbg shear 4)Baker Premier Packer 5)CMU sliding sleeve 6)DB nipple 2.75"ID Lower Completion: "' 10-3/4"60#L-80 BTC 7)Plop and drop liner in C sand 4 Surface Casing at 2,379'MD -no junction -4.5"12.6#L-80 w/perf pups 8)ZXP liner top packer&Flexlock Liner Hanger XO 5"Hydril 521 Box X 4-W IBTM pin -4.5"12.6#L-80 w/Frac Ports 3-1/2" 9.3#L-80 eue8rd 7 5/8"29#L-80 Hyd 563 • t+9 C sand Lateral Intermediate Casing at 15,067'MD by 6 3/4"Hole TD d 14,132'-27,000'MD 04-1/4"12.6#L-80 Liner w/pert pups 0 0 0 0 0 0 0 0 0 0 0 0 Production Packer at 13,500'MD CMU Sliding sleeve for 1:::,. /� 4'/z"12.6#L-80 Liner w/frac ports Selectivity "'""'' ' I o 0 0 0 0 0 0 0 o u o u o .0 3-1/2" 9.3#TN110SS "q.:::::::... :::.....:. A sand Lateral Production Pac e -t 6 3/4"Hole TD 14,192'Mi ZXP liner top packer(whipstock 15,067'-27,000'MD base)at 14,232'MD CD5-18 APD Page 15 of 15 Printed:6-Sep-16 • • CD5-18wp06 (70) 6.983 Plan Summary `m Base Permafrost Alpine 84 _ a', I \ Alpine A ( 2 - ( 110-3/4"x 13-10'1 i 7-518"X 9-7/8"by 11"1 I JI-'� - Alpine C - ` y a I I I I I I I I t\ I I 1 I I I I 1 I I i I D `1 r,�-� '0 6000 12000 18000 24000 I �` 120"x42"1 Measured Depth 14-12"x6-3/4 �® I � 0-.-04, 0 120"x 42"1 Depth Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) °. Rig' Doyon 19 _. ;.�• Oo o__110-3/4"x 13-1/21 Y o O - o P yo 000 O f V) _ 0 Noo�0 000 00 0 7-518"X 9-718"by 11"1 I4-12"x 6-3/4"1 0, O, O o � I o - ^ ^o 00 0 0 0,0 0 0 0 0 0 0 0 0 0 0 0 O ^ , 0000000000000Qek II 0 ^NOVO 00i (o n CO 0 0 EA N 0 V 0 W ^ ,..r .- - - •- N 0 N N N N N\ N -' ..... . I j O CJ C] O O O O O O ..- 1- i �.. I L.. I I. I � iI I I I - I I L. I I i :..I I 36 300 0 2500 5000 7500 10000 12500 1 50 00 17500 20000 22500 25000 0 300 - 490 Horizontal Departure - 330 _.' w ., ,i -"MEM - 670 _ 670 - 860 - t: ..:.: D) rZ 'e.:s 3 $F�!/ 860 - 1040 o i, ill 11111111111111111 I .`8 ` �I _ Im9no 1040 - 1230 .El 60 .___. .._.. 308 F- /, a `' 1 -">' 60 1230 - 1410 a _. L ,,.:. -' 1410 - 1600 a (0111 • .,.jam 1600 - 2660 Minor Risked c 1 --- 2660 3730 �j 30 ' _ 414, !1 ��li _t %i' 3 3730 - 4790 p ii 1 270 ��1 4 -- - - .41.111111 0 4790 - 5850 m _. - i s- �" 3 J I 5850 - 6910 •E' _. r i -',...: 6910 - 7970 1195 0 / �• , rn.e'. 7970 - 9040 0 _ tbaoa 9040 - 10100" 110.5 . �� � .� 10100 - 12210 0 3500 7000 1 05 00 14000 17500 21000 24500240 cos.iauyselrol Ifo 12210 - 14330 SURVEY PROGRAM 14330 - 16440 ' 16440 - 18550 epth From Depth To Survey/Plan Tool pad Elevati on 33.90 16550 - 20660 36.30 400.00 CD5-18wp06(7D)(Plan:CD5-18) INC 210 -- -- - tao 36.30 400.00 CD5-18wp06(7D)(Plan:CD5-18) GYD-GC-SS - 20660 22770 400.00 1400.00 CD5-18wp06(7D)(Plan:CD5-18) MWD 24890 CASING DETAILS 180 22770 "-' 400.00 2378.95 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC 24890 - 27000 2378.95 3878.95 CD5-18wp06(7D)(Plan:CD5-18) MWD TVD MD Name 2378.95 15067.06 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC 115.30 115.30 20"x42" Magnetic Model: BGGM2016 TM 15067.06 16567.06 CD5-18wp06(7D)(Plan:CD5-18) MWD 2185.20 2378.95 103/4"x 13-1/2" Magnetic Model Date: 01-Oct-16 15067.06 27000.00 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC 7609.20 15067.06 7-5/8"X 9-7/8"by 11" Magnetic Declination: 17.52° 7730.33 27000.00 4-1/2"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 17.52°East SECTION DETAILS = 1320.2 Sec MD Inc Azi ND ON/-S +FJ-W Dleg TFace VSect Target Annotation 1 38.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.51100'OLS,170°TF,far 300.31' 3 600.31 4.50 170.00 600.00 -11.62 2.05 1.50 170.00 11.22 Start 2.51100'DLS,0°IF,for 690.83' 4 1291.14 21.78 170.00 1270.20 -165.70 29.22 2.50 0.00 160.02 Hold for 107.88' 5 1398.82 21.78 170.00 1370.20 -205.04 36.15 0.00 0.00 198.01 Start 37100'M.S.52.34°IF,for 980.13' 6 2378.95 45.75 137.14 2185.20 -651.25 312.61 3.00 -52.34 721.78 Hold for20' 7 2398.95 45.75 137.14 2199.15 -661.75 322.35 0.00 0.00 735.63 Start 35100'DLS,-31.76°IF,for 634.61' 8 3033.56 62.56 125.99 2570.21 -996,92 708.37 3.00 -31.76 1212.79 Hold for 10050.45' 9 13084.02 62.56 125.99 7202.31 -6237.89 7925.54 0.00 0.00 9228.54 Start 31100'DLS,55.96°TF,for 1048.25' 10 14132.26 82.30 151.85 7522.17 -6988.09 8563.04 3.00 55.9610190.22 CD5-07D 00.AIpCKO 041916 JD Start 27100'OLS,0.01*TF,for 117.99' 11 14250.25 84.66 151.85 7535.57 -7091.44 8618.34 2.00 0.01 10307.44 Hold for699.8' 12 14950.05 84.66 151.85 7600.69 -7705.79 8947.05 0.00 0.0011004.20 Start 27100'DLS,-0.1°TF,for 117.01' 13 15067.06 87.00 151.85 7609.20 -7808.68 9002.11 2.00 -0.1011120.89 CD5-07D 01.Heel 041416 JD Hold for 20' 14 15087.06 87.00 151.85 7610.25 -7826.29 9011.53 0.00 0.00 11140.86 Start 37100'DLS,0°TF,for 81.02' 15 15188,08 89,43 151.85 7612.77 -7897.68 9049.74 3.00 0.0011221.84 Hold for 8900.16' 16 24068.24 89.43 151.85 7701.20-15744.43 13248.97 0.00 0.00 20121.52 CD5-070 02.Toe 041416 JD Adjust TF to 0°,for 2931.76' 17 27000.00 89.43 151.85 7730.33-18329.19 14632.22 0.00 0.00 23053.13 TO:27000'MD,7730.33'TVD Base Permafrost Survey program If clean MWD surveys changed to include not acquired by 500' INC only toolcode MD, plan to keep Gyro for the first 400' on standby and run MD, and Gyro every stand until depth shortened to magnetic interference 400' as well. clears up. 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 avoid pre plan as set out in the aurin nook approve it as the basis for the final well olan and wellsite drawings I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance Prepared by: Checked by: Accepted by: Approved by- I Brij Polnis Nate Beck Erik Sterk Will Earhart 0 41110 17:47,September 01 2016 Easting(6000 usft/in) MUM D5-09 \ e rv' l` �� . . I:■ CD1-47 CD -12 \. 11,�, ■ F�1 ne3.. 1 e1-03A CD5-e CD `` C CD -03 CD274 �`iql, ( �. .3,:.::, D 'r g B1 CD1-226 CD '3 \ �iI.' •.e /� .e.• • .• C■•-07 �••: A11_-47P o� ��+,81 ��� ■'46 ��i�GQ 1�L'B5 r.ec.P�Y26 i\ \ \ If . V,,,: 2., CD5-.- 4 `\\� L - 0•2.•-- _..CD1 Alpine R CD2- ' ` k�,. CD2 Alpine Pae '""� D 04 \x , � 1Af- CD2 \r:r7rG _ * -• r ` a =. Cr, N gs-ut - =. ,.►! I I v.� Cs e, - �, tl1=48 CD I G �� ;i,.- y i•-19 ` li CD5 Alpine West Pad �i5'�i�j, .ii/k \`\ �.) . k qt-229I if fit \5� ._ c. t? W .1CD1-37 ��4� - CD4-0 �� '.•-45 ■18PB1 - 1/:�1�••-33 e 0.• \ Ce•-35 38 w �ioir� D2-3 iii \�•:a "--39 CD - - ��/�`,,'' e,e r, e.C4.•_ :•,�..;.1wp•4 1-48A o _ e5-21 ` CD2, •wp,. . to Ce•_,.�, e la t _ \\ CD 6 �.•7 ■••-58.1 CD2-52 �,•c c_ ?. . CDt- X149 E - CD5■1 a ■y�• \ c o - A CD5-05 ' D`•i•.,.. 6 C■• A...:k. •'-CD2-27 4-•3016 Z - D5-08 CIA•6 \ \ k e `- .- a . CD 2wp0 �- CD.-'.,•.i<):■• �' ��_ r CD4 I11an€�q Pad 3111161%.11,77 -7,--,..:;,--, ��` rz I CD5-315PB1 CD -31 'B1 �-.. .11., _ ,� /4 e,A2� �► .mil Y r�14 Vfli*/1/1 ■4'21 CD4 CD4-286 CD5 314XP61 .04t�` s�� 4C,. .. .CD5-316PB1wp.• C■.18L wp05.1 1`� 11:��, e.q_ 0 , � 1► ,cI CD5-313 CD 17 ■,•.re /,� St,, Ce�` 288v. ro 1„ ,•., CD4912 2 CD4-295— CD5-99... r 'i: '. \ r.' • ' ''a.rdi 5 _ Ne1:v!',�••,' .•.214 C■ 191ap9�n, I D) .•B1 CD4- PB3 — CD5-315 CD5-316wp03 CD5-18wp06(7D) CD4-9.•' - - CD5-314Xwp04 CD4-9.•P= r r i ) ) ) ) i ) ) ) ) ) ) ) ) 1 1 1 CD a ".t''.'c-' 7V4lRN01 • Easting(6000 usft/in) • • CD5-18wp06 (7D) Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. Ati0— 20"x42'------- 10-3/4" x 13-1/2" O° 0° ,\° O° O° es) °00 -3500— 0 ^° ^°° °° "^ ^moo Q. o0 N 1bs000 +-7000 CD5-07D 00.AIpCKO 041916 JD1500° `\ ,k00° o CD5-18 Polygon 090116,EP0 0 z -- \ 1�p0 CD5-07D 01 Heel 041416 JD \ 18000 '3.010500— \ 190°0 \130°° 9"1°00 7-5/8"X 9-7/8"by 11" 200 0 -14000— \ 236P b,°°° 06 l pl CD5-07D 02.Toe 041416.�D \ 250°° Gp "1 6°00 -17500— \ 2 :06 4-1/2"x 6-3/4'1-\ 1._ I - I - I I I I -3500 0 3500 7000 10500 14000 17500 21000 West(-)/East(+) • . CD5-18wp06 (7D) Section View 0° 20"x 42" Base Permafrost 1p00 1500- 300 -2° ®moo 10-3/4" x 13-1/2" '� o0 co _c 3000- o0 a 4o a) p o0 To o0 U o f �o S 4500- Qb It ,® 0000 0 ^0000 000 Alpine C Alpine B4 co 6000— 0 L/, foo Alpine A a ',' -i:i---iii J , CV CV : 7500 _ --1--__ _ _ ,-- _ _- ---- ----- I 7-5/8"X 9-7/8"by 11" 'I I 0 3000 6000 9000 12000 15000 18000 21000 4-1/2"x 6-3/4" Vertical Section at 152.00° • S CD5-18wp06 (7D) Section View 7395 Alpine C Alpine B4 0 0 0 7480- d s Alpine A Q _7565 ,,_ o _ .�_ 0 N in o CO U 0 0 a co 0 0 _.D_. O _... co co O OO O l() rn o 0 O 0 � ,' i N I 0 O C) 7650 7-5/8" X 9-7/8" by 11" Np0j o 0 N O O N in O o , N O O ,N 7735 4-1/2"x 6-3/4" 7820 i 1 —r I I I I 10000 12000 14000 16000 18000 20000 22000 24000 Vertical Section at 152.00° • II ' Ii \ \ \ � \ � } \ � } \ \ C o n o c o P hills ps(Alaska) Inc. -W N S Western North Slope , CD5 Alpine West Pad \ \ Plan: CD5-18 (7D) Plan: CD5-18 \ \ ) � \ \ \ \ } \ \ Plan: CD5-18wp06 (7D) } � \ } \ \ \ \ \ Standard Proposal Report 01 September, 2016 \ \ , \ � \ \ \ � \ \ \ \ \ \ \ \ \ \ \ \ 2 » / « + I . » \ �: \ / I i SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Project Western North Slope,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Well Plan:CD5-18(7D) Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 33.90 usft Wellbore Plan:CD5-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2016 10/1/2016 17.52 80.81 57,510 Design CD5-18wp06(7D) 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 0.00 152.00 9/1/2016 5:32:59PM Page 2 COMPASS 5000.1 Build 74 • S SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 36.30 0.00 0.00 36.30 -33.90 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 229.80 0.00 0.00 0.00 0.00 0.00 0.00 600.31 4.50 170.00 600.00 529.80 -11.62 2.05 1.50 1.50 0.00 170.00 1,291.14 21.78 170.00 1,270.20 1,200.00 -165.70 29.22 2.50 2.50 0.00 0.00 1,398.82 21.78 170.00 1,370.20 1,300.00 -205.04 36.15 0.00 0.00 0.00 0.00 2,378.95 45.75 137.14 2,185.20 2,115.00 -651.25 312.61 3.00 2.45 -3.35 -52.34 2,398.95 45.75 137.14 2,199.15 2,128.95 -661.75 322.35 0.00 0.00 0.00 0.00 3,033.56 62.56 125.99 2,570.21 2,500.01 -996.92 708.37 3.00 2.65 -1.76 -31.76 13,084.02 62.56 125.99 7,202.31 7,132.11 -6,237.89 7,925.54 0.00 0.00 0.00 0.00 14,132.26 82.30 151.85 7,522.17 7,451.97 -6,988.09 8,563.04 3.00 1.88 2.47 55.96 14,250.25 84.66 151.85 7,535.57 7,465.37 -7,091.44 8,618.34 2.00 2.00 0.00 0.01 14,950.05 84.66 151.85 7,600.69 7,530.49 -7,705.79 8,947.05 0.00 0.00 0.00 0.00 15,067.06 87.00 151.85 7,609.20 7,539.00 -7,808.68 9,002.11 2.00 2.00 0.00 -0.10 15,087.06 87.00 151.85 7,610.25 7,540.05 • -7,826.29 9,011.53 0.00 0.00 0.00 0.00 15,168.08 89.43 151.85 7,612.77 7,542.57 -7,897.68 9,049.74 3.00 3.00 0.00 0.00 24,068.24 89.43 151.85 7,701.20 7,631.00 -15,744.43 13,248.97 0.00 0.00 0.00 0.00 27,000.00 89.43 151.85 7,730.33 7,660.13 -18,329.19 14,632.22 0.00 0.00 0.00 0.00 9/1/2016 5:32:59PM Page 3 COMPASS 5000.1 Build 74 • 0 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3©70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3©70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) -33.90 36.30 0.00 0.00 36.30 -33.90 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 29.80 0.00 0.00 0.00 0.00 115.30 0.00 0.00 115.30 45.10 0.00 0.00 0.00 0.00 20"x 42" 200.00 0.00 0.00 200.00 129.80 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 229.80 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,170°TF,for 300.31' 400.00 1.50 170.00 399.99 329.79 -1.29 0.23 1.50 1.24 500.00 3.00 170.00 499.91 429.71 -5.16 0.91 1.50 4.98 600.00 4.50 170.00 599.69 529.49 -11.60 2.04 1.50 11.20 600.31 4.50 170.00 600.00 529.80 -11.62 2.05 1.50 11.22 Start 2.5°1100`DLS,0°TF,for 690.83' 700.00 7.00 170.00 699.18 628.98 -21.46 3.78 2.50 20.72 800.00 9.50 170.00 798.14 727.94 -35.58 6.27 2.50 34.36 900.00 12.00 170.00 896.38 826.18 -53.94 9.51 2.50 52.10 1,000.00 14.50 170.00 993.71 923.51 -76.51 13.49 2.50 73.89 1,100.00 17.00 170.00 1,089.95 1,019.75 -103.23 18.20 2.50 99.70 1,200.00 19.50 170.00 1,184.91 1,114.71 -134.07 23.64 2.50 129.47 1,291.14 21.78 170.00 1,270.20 1,200.00 -165.70 29.22 2.50 160.02 Hold for 107.68' 1,300.00 21.78 170.00 1,278.43 1,208.23 -168.93 29.79 0.00 163.14 1,344.98 21.78 170.00 1,320.20 1,250.00 -185.37 32.69 0.00 179.01 Base Permafrost 1,398.82 21.78 170.00 1,370.20 1,300.00 -205.04 36.15 0.00 198.01 Start 3"/100'DLS,-52.34°TF,for 980.13' 1,400.00 21.80 169.92 1,371.29 1,301.09 -205.47 36.23 3.00 198.43 1,500.00 23.75 164.02 1,463.50 1,393.30 -243.11 45.02 3.00 235.79 1,600.00 25.89 159.01 1,554.28 1,484.08 -282.86 58.38 3.00 277.16 1,700.00 28.17 154.73 1,643.36 1,573.16 -324.60 76.28 3.00 322.41 1,800.00 30.57 151.06 1,730.50 1,660.30 -368.21 98.67 3.00 371.43 1,900.00 33.06 147.89 1,815.47 1,745.27 -413.58 125.48 3.00 424.08 2,000.00 35.63 145.12 1,898.04 1,827.84 -460.59 156.65 3.00 480.22 2,100.00 38.24 142.67 1,977.97 1,907.77 -509.10 192.08 3.00 539.69 2,200.00 40.90 140.50 2,055.04 1,984.84 -558.99 231.68 3.00 602.32 2,300.00 43.60 138.55 2,129.06 2,058.86 -610.11 275.34 3.00 667.96 2,378.95 45.75 137.14 2,185.20 2,115.00 -651.25 312.61 3.00 721.78 Hold for 20'-10-314"x 13-1/2" 2,398.95 45.75 137.14 2,199.15 2,128.95 -661.75 322.35 0.00 735.63 Start 3°/100'DLS,-31.76°TF,for 634.61' 2,400.00 45.78 137.12 2,199.88 2,129.68 -662.30 322.86 3.00 736.35 2,500.00 48.35 135.01 2,268.00 2,197.80 -714.99 373.67 3.00 806.73 2,600.00 50.96 133.06 2,332.73 2,262.53 -767.94 428.48 3.00 879.21 2,700.00 53.60 131.25 2,393.92 2,323.72 -821.00 487.12 3.00 953.59 2,800.00 56.26 129.56 2,451.37 2,381.17 -874.03 549.45 3.00 1,029.67 2,900.00 58.94 127.97 2,504.95 2,434.75 -926.87 615.28 3.00 1,107.24 9/1/2016 5:32:59PM Page 4 COMPASS 5000.1 Build 74 41, • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3©70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3©70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 2,484.31 3,000.00 61.65 126.47 2,554.51 2,484.31 -979.39 684.44 3.00 1,186.08 3,033.56 62.56 125.99 2,570.21 2,500.01 -996.92 708.37 3.00 1,212.79 Hold for 10050.45' 3,100.00 62.56 125.99 2,600.83 2,530.63 -1,031.57 756.08 0.00 1,265.78 3,200.00 62.56 125.99 2,646.92 2,576.72 -1,083.71 827.89 0.00 1,345.53 3,300.00 62.56 125.99 2,693.01 2,622.81 -1,135.86 899.70 0.00 1,425.29 3,400.00 62.56 125.99 2,739.10 2,668.90 -1,188.01 971.51 0.00 1,505.04 3,500.00 62.56 125.99 2,785.19 2,714.99 -1,240.15 1,043.32 0.00 1,584.80 3,600.00 62.56 125.99 2,831.27 2,761.07 -1,292.30 1,115.13 0.00 1,664.55 3,700.00 62.56 125.99 2,877.36 2,807.16 -1,344.45 1,186.94 0.00 1,744.31 3,800.00 62.56 125.99 2,923.45 2,853.25 -1,396.59 1,258.75 0.00 1,824.06 3,900.00 62.56 125.99 2,969.54 2,899.34 -1,448.74 1,330.55 0.00 1,903.82 4,000.00 62.56 125.99 3,015.63 2,945.43 -1,500.89 1,402.36 0.00 1,983.57 4,100.00 62.56 125.99 3,061.72 2,991.52 -1,553.03 1,474.17 0.00 2,063.33 4,200.00 62.56 125.99 3,107.80 3,037.60 -1,605.18 1,545.98 0.00 2,143.08 4,300.00 62.56 125.99 3,153.89 3,083.69 -1,657.33 1,617.79 0.00 2,222.84 4,400.00 62.56 125.99 3,199.98 3,129.78 -1,709.47 1,689.60 0.00 2,302.60 4,500.00 62.56 125.99 3,246.07 3,175.87 -1,761.62 1,761.41 0.00 2,382.35 4,600.00 62.56 125.99 3,292.16 3,221.96 -1,813.77 1,833.22 0.00 2,462.11 4,700.00 62.56 125.99 3,338.25 3,268.05 -1,865.91 1,905.03 0.00 2,541.86 4,800.00 62.56 125.99 3,384.34 3,314.14 -1,918.06 1,976.84 0.00 2,621.62 4,900.00 62.56 125.99 3,430.42 3,360.22 -1,970.21 2,048.65 0.00 2,701.37 5,000.00 62.56 125.99 3,476.51 3,406.31 -2,022.35 2,120.46 0.00 2,781.13 5,100.00 62.56 125.99 3,522.60 3,452.40 -2,074.50 2,192.27 0.00 2,860.88 5,200.00 62.56 125.99 3,568.69 3,498.49 -2,126.65 2,264.08 0.00 2,940.64 5,300.00 62.56 125.99 3,614.78 3,544.58 -2,178.79 2,335.89 0.00 3,020.39 5,400.00 62.56 125.99 3,660.87 3,590.67 -2,230.94 2,407.70 0.00 3,100.15 5,500.00 62.56 125.99 3,706.96 3,636.76 -2,283.09 2,479.50 0.00 3,179.90 5,600.00 62.56 125.99 3,753.04 3,682.84 -2,335.23 2,551.31 0.00 3,259.66 5,700.00 62.56 125.99 3,799.13 3,728.93 -2,387.38 2,623.12 0.00 3,339.41 5,800.00 62.56 125.99 3,845.22 3,775.02 -2,439.52 2,694.93 0.00 3,419.17 5,900.00 62.56 125.99 3,891.31 3,821.11 -2,491.67 2,766.74 0.00 3,498.92 6,000.00 62.56 125.99 3,937.40 3,867.20 -2,543.82 2,838.55 0.00 3,578.68 6,100.00 62.56 125.99 3,983.49 3,913.29 -2,595.96 2,910.36 0.00 3,658.43 6,200.00 62.56 125.99 4,029.57 3,959.37 -2,648.11 2,982.17 0.00 3,738.19 6,300.00 62.56 125.99 4,075.66 4,005.46 -2,700.26 3,053.98 0.00 3,817.94 6,400.00 62.56 125.99 4,121.75 4,051.55 -2,752.40 3,125.79 0.00 3,897.70 6,500.00 62.56 125.99 4,167.84 4,097.64 -2,804.55 3,197.60 0.00 3,977.45 6,600.00 62.56 125.99 4,213.93 4,143.73 -2,856.70 3,269.41 0.00 4,057.21 6,700.00 62.56 125.99 4,260.02 4,189.82 -2,908.84 3,341.22 0.00 4,136.96 6,800.00 62.56 125.99 4,306.11 4,235.91 -2,960.99 3,413.03 0.00 4,216.72 6,900.00 62.56 125.99 4,352.19 4,281.99 -3,013.14 3,484.84 0.00 4,296.47 7,000.00 62.56 125.99 4,398.28 4,328.08 -3,065.28 3,556.65 0.00 4,376.23 7,100.00 62.56 125.99 4,444.37 4,374.17 -3,117.43 3,628.45 0.00 4,455.98 7,200.00 62.56 125.99 4,490.46 4,420.26 -3,169.58 3,700.26 0.00 4,535.74 9/1/2016 5:32:59PM Page 5 COMPASS 5000.1 Build 74 • S SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) I Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 4,466.35 7,300.00 62.56 125.99 4,536.55 4,466.35 -3,221.72 3,772.07 0.00 4,615.49 7,400.00 62.56 125.99 4,582.64 4,512.44 -3,273.87 3,843.88 0.00 4,695.25 7,500.00 62.56 125.99 4,628.72 4,558.52 -3,326.02 3,915.69 0.00 4,775.00 7,600.00 62.56 125.99 4,674.81 4,604.61 -3,378.16 3,987.50 0.00 4,854.76 7,700.00 62.56 125.99 4,720.90 4,650.70 -3,430.31 4,059.31 0.00 4,934.51 7,800.00 62.56 125.99 4,766.99 4,696.79 -3,482.46 4,131.12 0.00 5,014.27 7,900.00 62.56 125.99 4,813.08 4,742.88 -3,534.60 4,202.93 0.00 5,094.02 8,000.00 62.56 125.99 4,859.17 4,788.97 -3,586.75 4,274.74 0.00 5,173.78 8,100.00 62.56 125.99 4,905.26 4,835.06 -3,638.90 4,346.55 0.00 5,253.54 8,200.00 62.56 125.99 4,951.34 4,881.14 -3,691.04 4,418.36 0.00 5,333.29 8,300.00 62.56 125.99 4,997.43 4,927.23 -3,743.19 4,490.17 0.00 5,413.05 8,400.00 62.56 125.99 5,043.52 4,973.32 -3,795.34 4,561.98 0.00 5,492.80 8,500.00 62.56 125.99 5,089.61 5,019.41 -3,847.48 4,633.79 0.00 5,572.56 8,600.00 62.56 125.99 5,135.70 5,065.50 -3,899.63 4,705.60 0.00 5,652.31 8,700.00 62.56 125.99 5,181.79 5,111.59 -3,951.77 4,777.41 0.00 5,732.07 8,800.00 62.56 125.99 5,227.88 5,157.68 -4,003.92 4,849.21 0.00 5,811.82 8,900.00 62.56 125.99 5,273.96 5,203.76 -4,056.07 4,921.02 0.00 5,891.58 9,000.00 62.56 125.99 5,320.05 5,249.85 -4,108.21 4,992.83 0.00 5,971.33 9,100.00 62.56 125.99 5,366.14 5,295.94 -4,160.36 5,064.64 0.00 6,051.09 9,200.00 62.56 125.99 5,412.23 5,342.03 -4,212.51 5,136.45 0.00 6,130.84 9,300.00 62.56 125.99 5,458.32 5,388.12 -4,264.65 5,208.26 0.00 6,210.60 9,400.00 62.56 125.99 5,504.41 5,434.21 -4,316.80 5,280.07 0.00 6,290.35 9,500.00 62.56 125.99 5,550.49 5,480.29 -4,368.95 5,351.88 0.00 6,370.11 9,600.00 62.56 125.99 5,596.58 5,526.38 -4,421.09 5,423.69 0.00 6,449.86 9,700.00 62.56 125.99 5,642.67 5,572.47 -4,473.24 5,495.50 0.00 6,529.62 9,800.00 62.56 125.99 5,688.76 5,618.56 -4,525.39 5,567.31 0.00 6,609.37 9,900.00 62.56 125.99 5,734.85 5,664.65 -4,577.53 5,639.12 0.00 6,689.13 10,000.00 62.56 125.99 5,780.94 5,710.74 -4,629.68 5,710.93 0.00 6,768.88 10,100.00 62.56 125.99 5,827.03 5,756.83 -4,681.83 5,782.74 0.00 6,848.64 10,200.00 62.56 125.99 5,873.11 5,802.91 -4,733.97 5,854.55 0.00 6,928.39 10,300.00 62.56 125.99 5,919.20 5,849.00 -4,786.12 5,926.36 0.00 7,008.15 10,400.00 62.56 125.99 5,965.29 5,895.09 -4,838.27 5,998.16 0.00 7,087.90 10,500.00 62.56 125.99 6,011.38 5,941.18 -4,890.41 6,069.97 0.00 7,167.66 10,600.00 62.56 125.99 6,057.47 5,987.27 -4,942.56 6,141.78 0.00 7,247.41 10,700.00 62.56 125.99 6,103.56 6,033.36 -4,994.71 6,213.59 0.00 7,327.17 10,800.00 62.56 125.99 6,149.65 6,079.45 -5,046.85 6,285.40 0.00 7,406.92 10,900.00 62.56 125.99 6,195.73 6,125.53 -5,099.00 6,357.21 0.00 7,486.68 11,000.00 62.56 125.99 6,241.82 6,171.62 -5,151.15 6,429.02 0.00 7,566.43 11,100.00 62.56 125.99 6,287.91 6,217.71 -5,203.29 6,500.83 0.00 7,646.19 11,200.00 62.56 125.99 6,334.00 6,263.80 -5,255.44 6,572.64 0.00 7,725.94 11,300.00 62.56 125.99 6,380.09 6,309.89 -5,307.58 6,644.45 0.00 7,805.70 11,400.00 62.56 125.99 6,426.18 6,355.98 -5,359.73 6,716.26 0.00 7,885.45 11,500.00 62.56 125.99 6,472.26 6,402.06 -5,411.88 6,788.07 0.00 7,965.21 11,600.00 62.56 125.99 6,518.35 6,448.15 -5,464.02 6,859.88 0.00 8,044.96 11,700.00 62.56 125.99 6,564.44 6,494.24 -5,516.17 6,931.69 0.00 8,124.72 9/1/2016 5:32:59PM Page 6 COMPASS 5000.1 Build 74 0 s SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-VVNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 6,540.33 11,800.00 62.56 125.99 6,610.53 6,540.33 -5,568.32 7,003.50 0.00 8,204.48 11,900.00 62.56 125.99 6,656.62 6,586.42 -5,620.46 7,075.31 0.00 8,284.23 12,000.00 62.56 125.99 6,702.71 6,632.51 -5,672.61 7,147.11 0.00 8,363.99 12,100.00 62.56 125.99 6,748.80 6,678.60 -5,724.76 7,218.92 0.00 8,443.74 12,200.00 62.56 125.99 6,794.88 6,724.68 -5,776.90 7,290.73 0.00 8,523.50 12,300.00 62.56 125.99 6,840.97 6,770.77 -5,829.05 7,362.54 0.00 8,603.25 12,400.00 62.56 125.99 6,887.06 6,816.86 -5,881.20 7,434.35 0.00 8,683.01 12,500.00 62.56 125.99 6,933.15 6,862.95 -5,933.34 7,506.16 0.00 8,762.76 12,600.00 62.56 125.99 6,979.24 6,909.04 -5,985.49 7,577.97 0.00 8,842.52 12,700.00 62.56 125.99 7,025.33 6,955.13 -6,037.64 7,649.78 0.00 8,922.27 12,800.00 62.56 125.99 7,071.42 7,001.22 -6,089.78 7,721.59 0.00 9,002.03 12,900.00 62.56 125.99 7,117.50 7,047.30 -6,141.93 7,793.40 0.00 9,081.78 13,000.00 62.56 125.99 7,163.59 7,093.39 -6,194.08 7,865.21 0.00 9,161.54 13,084.02 62.56 125.99 7,202.31 7,132.11 -6,237.89 7,925.54 0.00 9,228.54 Start 3'/100'DLS,55.96 TF,for 1048.25' 13,100.00 62.82 126.43 7,209.65 7,139.45 -6,246.28 7,937.00 3.00 9,241.33 13,200.00 64.54 129.18 7,253.99 7,183.79 -6,301.23 8,007.80 3.00 9,323.09 13,300.00 66.30 131.85 7,295.58 7,225.38 -6,360.31 8,076.91 3.00 9,407.70 13,400.00 68.11 134.44 7,334.33 7,264.13 -6,423.35 8,144.16 3.00 9,494.93 13,500.00 69.96 136.97 7,370.10 7,299.90 -6,490.19 8,209.35 3.00 9,584.56 13,600.00 71.85 ' 139.44 7,402.82 7,332.62 -6,560.65 8,272.31 3.00 9,676.32 13,700.00 73.76 141.86 7,432.39 7,362.19 -6,634.52 8,332.86 3.00 9,769.97 13,800.00 75.70 144.23 7,458.72 7,388.52 -6,711.61 8,390.84 3.00 9,865.26 13,900.00 77.67 146.56 7,481.76 7,411.56 -6,791.70 8,446.08 3.00 9,961.91 14,000.00 79.65 148.86 7,501.42 7,431.22 -6,874.58 8,498.45 3.00 10,059.67 14,100.00 81.65 151.12 7,517.67 7,447.47 -6,960.02 8,547.79 3.00 10,158.27 14,132.26 82.30 151.85 7,522.17 7,451.97 -6,988.09 8,563.04 3.00 10,190.22 Start 2°1100'DLS,0.01°TF,for 117.99' 14,200.00 83.65 151.85 7,530.45 7,460.25 -7,047.36 8,594.75 2.00 10,257.45 14,250.25 84.66 151.85 7,535.57 7,465.37 -7,091.44 8,618.34 2.00 10,307.44 Hold for 699.8' 14,300.00 84.66 151.85 7,540.20 7,470.00 -7,135.12 8,641.71 0.00 10,356.97 14,300.04 84.66 151.85 7,540.20 7,470.00 -7,135.15 8,641.72 0.00 10,357.01 Alpine C 14,400.00 84.66 151.85 7,549.50 7,479.30 -7,222.90 8,688.68 0.00 10,456.53 14,500.00 84.66 151.85 7,558.81 7,488.61 -7,310.69 8,735.65 0.00 10,556.10 14,514.95 84.66 151.85 7,560.20 7,490.00 -7,323.82 8,742.67 0.00 10,570.98 Alpine B4 14,600.00 84.66 151.85 7,568.12 7,497.92 -7,398.48 8,782.62 0.00 10,655.67 14,700.00 84.66 151.85 7,577.42 7,507.22 -7,486.27 8,829.60 0.00 10,755.23 14,800.00 84.66 151.85 7,586.73 7,516.53 -7,574.06 8,876.57 0.00 10,854.80 14,900.00 84.66 151.85 7,596.03 7,525.83 -7,661.85 8,923.54 0.00 10,954.36 14,950.05 84.66 151.85 7,600.69 7,530.49 -7,705.79 8,947.05 0.00 11,004.20 Start 2°/100'DLS,-0.1°TF,for 117.01' 15,000.00 85.66 151.85 7,604.91 7,534.71 -7,749.67 8,970.53 2.00 11,053.97 9/1/2016 5:32:59PM Page 7 COMPASS 5000.1 Build 74 • S SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3©70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 7,539.00 15,067.06 87.00 151.85 7,609.20 7,539.00 -7,808.68 9,002.11 2.00 11,120.89 Hold for 20'-Alpine A-7-55/8"X 9-718 by 11" 15,087.06 87.00 151.85 7,610.25 7,540.05 -7,826.29 9,011.53 0.00 11,140.86 Start 3 1100'DLS,0°TF,for 81.02' 15,100.00 87.39 151.85 7,610.88 7,540.68 -7,837.68 9,017.63 3.00 11,153.78 15,168.08 89.43 151.85 7,612.77 7,542.57 -7,897.68 9,049.74 3.00 11,221.84 Hold for 8900-16` 15,200.00 89.43 151.85 7,613.09 7,542.89 -7,925.82 9,064.80 0.00 11,253.75 15,300.00 89.43 151.85 7,614.08 7,543.88 -8,013.99 9,111.98 0.00 11,353.75 15,400.00 89.43 151.85 7,615.07 7,544.87 -8,102.15 9,159.16 0.00 11,453.74 15,500.00 89.43 151.85 7,616.07 7,545.87 -8,190.31 9,206.34 0.00 11,553.74 15,600.00 89.43 151.85 7,617.06 7,546.86 -8,278.48 9,253.53 0.00 11,653.73 15,700.00 89.43 151.85 7,618.05 7,547.85 -8,366.64 9,300.71 0.00 11,753.73 15,800.00 89.43 151.85 7,619.05 7,548.85 -8,454.81 9,347.89 0.00 11,853.72 15,900.00 89.43 151.85 7,620.04 7,549.84 -8,542.97 9,395.07 0.00 11,953.71 16,000.00 89.43 151.85 7,621.04 7,550.84 -8,631.14 9,442.25 0.00 12,053.71 16,100.00 89.43 151.85 7,622.03 7,551.83 -8,719.30 9,489.43 0.00 12,153.70 16,200.00 89.43 151.85 7,623.02 7,552.82 -8,807.46 9,536.61 0.00 12,253.70 16,300.00 89.43 151.85 7,624.02 7,553.82 -8,895.63 9,583.80 0.00 12,353.69 16,400.00 89.43 151.85 7,625.01 7,554.81 -8,983.79 9,630.98 0.00 12,453.69 16,500.00 89.43 151.85 7,626.00 7,555.80 -9,071.96 9,678.16 0.00 12,553.68 16,600.00 89.43 151.85 7,627.00 7,556.80 -9,160.12 9,725.34 0.00 12,653.68 16,700.00 89.43 151.85 7,627.99 7,557.79 -9,248.28 9,772.52 0.00 12,753.67 16,800.00 89.43 151.85 7,628.98 7,558.78 -9,336.45 9,819.70 0.00 12,853.67 16,900.00 89.43 151.85 7,629.98 7,559.78 -9,424.61 9,866.89 0.00 12,953.66 17,000.00 89.43 151.85 7,630.97 7,560.77 -9,512.78 9,914.07 0.00 13,053.66 17,100.00 89.43 151.85 7,631.96 7,561.76 -9,600.94 9,961.25 0.00 13,153.65 17,200.00 89.43 151.85 7,632.96 7,562.76 -9,689.11 10,008.43 0.00 13,253.65 17,300.00 89.43 151.85 7,633.95 7,563.75 -9,777.27 10,055.61 0.00 13,353.64 17,400.00 89.43 151.85 7,634.95 7,564.75 -9,865.43 10,102.79 0.00 13,453.64 17,500.00 89.43 151.85 7,635.94 7,565.74 -9,953.60 10,149.97 0.00 13,553.63 17,600.00 89.43 151.85 7,636.93 7,566.73 -10,041.76 10,197.16 0.00 13,653.62 17,700.00 89.43 151.85 7,637.93 7,567.73 -10,129.93 10,244.34 0.00 13,753.62 17,800.00 89.43 151.85 7,638.92 7,568.72 -10,218.09 10,291.52 0.00 13,853.61 17,900.00 89.43 151.85 7,639.91 7,569.71 -10,306.25 10,338.70 0.00 13,953.61 18,000.00 89.43 151.85 7,640.91 7,570.71 -10,394.42 10,385.88 0.00 14,053.60 18,100.00 89.43 151.85 7,641.90 7,571.70 -10,482.58 10,433.06 0.00 14,153.60 18,200.00 89.43 151.85 7,642.89 7,572.69 -10,570.75 10,480.24 0.00 14,253.59 18,300.00 89.43 151.85 7,643.89 7,573.69 -10,658.91 10,527.43 0.00 14,353.59 18,400.00 89.43 151.85 7,644.88 7,574.68 -10,747.08 10,574.61 0.00 14,453.58 18,500.00 89.43 151.85 7,645.88 7,575.68 -10,835.24 10,621.79 0.00 14,553.58 18,600.00 89.43 151.85 7,646.87 7,576.67 -10,923.40 10,668.97 0.00 14,653.57 18,700.00 89.43 151.85 7,647.86 7,577.66 -11,011.57 10,716.15 0.00 14,753.57 18,800.00 89.43 151.85 7,648.86 7,578.66 -11,099.73 10,763.33 0.00 14,853.56 18,900.00 89.43 151.85 7,649.85 7,579.65 -11,187.90 10,810.52 0.00 14,953.56 9/1/2016 5:32:59PM Page 8 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: VVell Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey I Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +EI-W DLS Vert Section (usft) (°) (1 (usft) usft (usft) (usft) 7,580.64 19,000.00 89.43 151.85 7,650.84 7,580.64 -11,276.06 10,857.70 0.00 15,053.55 19,100.00 89.43 151.85 7,651.84 7,581.64 -11,364.22 10,904.88 0.00 15,153.55 19,200.00 89.43 151.85 7,652.83 7,582.63 -11,452.39 10,952.06 0.00 15,253.54 19,300.00 89.43 151.85 7,653.82 7,583.62 -11,540.55 10,999.24 0.00 15,353.53 19,400.00 89.43 151.85 7,654.82 7,584.62 -11,628.72 11,046.42 0.00 15,453.53 19,500.00 89.43 151.85 7,655.81 7,585.61 -11,716.88 11,093.60 0.00 15,553.52 19,600.00 89.43 151.85 7,656.80 7,586.60 -11,805.05 11,140.79 0.00 15,653.52 19,700.00 89.43 151.85 7,657.80 7,587.60 -11,893.21 11,187.97 0.00 15,753.51 19,800.00 89.43 151.85 7,658.79 7,588.59 -11,981.37 11,235.15 0.00 15,853.51 19,900.00 89.43 151.85 7,659.79 7,589.59 -12,069.54 11,282.33 0.00 15,953.50 20,000.00 89.43 151.85 7,660.78 7,590.58 -12,157.70 11,329.51 0.00 16,053.50 20,100.00 89.43 151.85 7,661.77 7,591.57 -12,245.87 11,376.69 0.00 16,153.49 20,200.00 89.43 151.85 7,662.77 7,592.57 -12,334.03 11,423.88 0.00 16,253.49 20,300.00 89.43 151.85 7,663.76 7,593.56 -12,422.19 11,471.06 0.00 16,353.48 20,400.00 89.43 151.85 7,664.75 7,594.55 -12,510.36 11,518.24 0.00 16,453.48 20,500.00 89.43 151.85 7,665.75 7,595.55 -12,598.52 11,565.42 0.00 16,553.47 20,600.00 89.43 151.85 7,666.74 7,596.54 -12,686.69 11,612.60 0.00 16,653.47 20,700.00 89.43 151.85 7,667.73 7,597.53 -12,774.85 11,659.78 0.00 16,753.46 20,800.00 89.43 151.85 7,668.73 7,598.53 -12,863.02 11,706.96 0.00 16,853.46 20,900.00 89.43 151.85 7,669.72 7,599.52 -12,951.18 11,754.15 0.00 16,953.45 21,000.00 89.43 151.85 7,670.71 7,600.51 -13,039.34 11,801.33 0.00 17,053.44 21,100.00 89.43 151.85 7,671.71 7,601.51 -13,127.51 11,848.51 0.00 17,153.44 21,200.00 89.43 151.85 7,672.70 7,602.50 -13,215.67 11,895.69 0.00 17,253.43 21,300.00 89.43 151.85 7,673.70 7,603.50 -13,303.84 11,942.87 0.00 17,353.43 21,400.00 89.43 151.85 7,674.69 7,604.49 -13,392.00 11,990.05 0.00 17,453.42 21,500.00 89.43 151.85 7,675.68 7,605.48 -13,480.16 12,037.23 0.00 17,553.42 21,600.00 89.43 151.85 7,676.68 7,606.48 -13,568.33 12,084.42 0.00 17,653.41 21,700.00 89.43 151.85 7,677.67 7,607.47 -13,656.49 12,131.60 0.00 17,753.41 21,800.00 89.43 151.85 7,678.66 7,608.46 -13,744.66 12,178.78 0.00 17,853.40 21,900.00 89.43 151.85 7,679.66 7,609.46 -13,832.82 12,225.96 0.00 17,953.40 22,000.00 89.43 151.85 7,680.65 7,610.45 -13,920.99 12,273.14 0.00 18,053.39 22,100.00 89.43 151.85 7,681.64 7,611.44 -14,009.15 12,320.32 0.00 18,153.39 22,200.00 89.43 151.85 7,682.64 7,612.44 -14,097.31 12,367.51 0.00 18,253.38 22,300.00 89.43 151.85 7,683.63 7,613.43 -14,185.48 12,414.69 0.00 18,353.38 22,400.00 89.43 151.85 7,684.62 7,614.42 -14,273.64 12,461.87 0.00 18,453.37 22,500.00 89.43 151.85 7,685.62 7,615.42 -14,361.81 12,509.05 0.00 18,553.37 22,600.00 89.43 151.85 7,686.61 7,616.41 -14,449.97 12,556.23 0.00 18,653.36 22,700.00 89.43 151.85 7,687.61 7,617.41 -14,538.13 12,603.41 0.00 18,753.35 22,800.00 89.43 151.85 7,688.60 7,618.40 -14,626.30 12,650.59 0.00 18,853.35 22,900.00 89.43 151.85 7,689.59 7,619.39 -14,714.46 12,697.78 0.00 18,953.34 23,000.00 89.43 151.85 7,690.59 7,620.39 -14,802.63 12,744.96 0.00 19,053.34 23,100.00 89.43 151.85 7,691.58 7,621.38 -14,890.79 12,792.14 0.00 19,153.33 23,200.00 89.43 151.85 7,692.57 7,622.37 -14,978.95 12,839.32 0.00 19,253.33 23,300.00 89.43 151.85 7,693.57 7,623.37 -15,067.12 12,886.50 0.00 19,353.32 23,400.00 89.43 151.85 7,694.56 7,624.36 -15,155.28 12,933.68 0.00 19,453.32 9/1/2016 5:32:59PM Page 9 COMPASS 5000.1 Build 74 • i SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-VVNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +EI-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 7,625.35 23,500.00 89.43 151.85 7,695.55 7,625.35 -15,243.45 12,980.86 0.00 19,553.31 23,600.00 89.43 151.85 7,696.55 7,626.35 -15,331.61 13,028.05 0.00 19,653.31 23,700.00 89.43 151.85 7,697.54 7,627.34 -15,419.78 13,075.23 0.00 19,753.30 23,800.00 89.43 151.85 7,698.53 7,628.33 -15,507.94 13,122.41 0.00 19,853.30 23,900.00 89.43 151.85 7,699.53 7,629.33 -15,596.10 13,169.59 0.00 19,953.29 24,000.00 89.43 151.85 7,700.52 7,630.32 -15,684.27 13,216.77 0.00 20,053.29 24,068.24 89.43 151.85 7,701.20 7,631.00 -15,744.43 13,248.97 0.00 20,121.52 Adjust TF to 0',for 2931.76' 24,100.00 89.43 151.85 7,701.52 7,631.32 -15,772.43 13,263.95 0.00 20,153.28 24,200.00 89.43 151.85 7,702.51 7,632.31 -15,860.60 13,311.14 0.00 20,253.27 24,300.00 89.43 151.85 7,703.50 7,633.30 -15,948.76 13,358.32 0.00 20,353.27 24,400.00 89.43 151.85 7,704.50 7,634.30 -16,036.92 13,405.50 0.00 20,453.26 24,500.00 89.43 151.85 7,705.49 7,635.29 -16,125.09 13,452.68 0.00 20,553.26 24,600.00 89.43 151.85 7,706.48 7,636.28 -16,213.25 13,499.86 0.00 20,653.25 24,700.00 89.43 151.85 7,707.48 7,637.28 -16,301.42 13,547.04 0.00 20,753.25 24,800.00 89.43 151.85 7,708.47 7,638.27 -16,389.58 13,594.22 0.00 20,853.24 24,900.00 89.43 151.85 7,709.46 7,639.26 -16,477.75 13,641.41 0.00 20,953.24 25,000.00 89.43 151.85 7,710.46 7,640.26 -16,565.91 13,688.59 0.00 21,053.23 25,100.00 89.43 151.85 7,711.45 7,641.25 -16,654.07 13,735.77 0.00 21,153.23 25,200.00 89.43 151.85 7,712.44 7,642.24 -16,742.24 13,782.95 0.00 21,253.22 25,300.00 89.43 151.85 7,713.44 7,643.24 -16,830.40 13,830.13 0.00 21,353.22 25,400.00 89.43 151.85 7,714.43 7,644.23 -16,918.57 13,877.31 0.00 21,453.21 25,500.00 89.43 151.85 7,715.43 7,645.23 -17,006.73 13,924.49 0.00 21,553.21 25,600.00 89.43 151.85 7,716.42 7,646.22 -17,094.89 13,971.68 0.00 21,653.20 25,700.00 89.43 151.85 7,717.41 7,647.21 -17,183.06 14,018.86 0.00 21,753.20 25,800.00 89.43 151.85 7,718.41 7,648.21 -17,271.22 14,066.04 0.00 21,853.19 25,900.00 89.43 151.85 7,719.40 7,649.20 -17,359.39 14,113.22 0.00 21,953.18 26,000.00 89.43 151.85 7,720.39 7,650.19 -17,447.55 14,160.40 0.00 22,053.18 26,100.00 89.43 151.85 7,721.39 7,651.19 -17,535.72 14,207.58 0.00 22,153.17 26,200.00 89.43 151.85 7,722.38 7,652.18 -17,623.88 14,254.77 0.00 22,253.17 26,300.00 89.43 151.85 7,723.37 7,653.17 -17,712.04 14,301.95 0.00 22,353.16 26,400.00 89.43 151.85 7,724.37 7,654.17 -17,800.21 14,349.13 0.00 22,453.16 26,500.00 89.43 151.85 7,725.36 7,655.16 -17,888.37 14,396.31 0.00 22,553.15 26,600.00 89.43 151.85 7,726.36 7,656.16 -17,976.54 14,443.49 0.00 22,653.15 26,700.00 89.43 151.85 7,727.35 7,657.15 -18,064.70 14,490.67 0.00 22,753.14 26,800.00 89.43 151.85 7,728.34 7,658.14 -18,152.86 14,537.85 0.00 22,853.14 26,900.00 89.43 151.85 7,729.34 7,659.14 -18,241.03 14,585.04 0.00 22,953.13 27,000.00 89.43 151.85 7,730.33 7,660.13 -18,329.19 14,632.22 0.00 23,053.13 TD:27000'MD,7730.33'TVD-4-1/2"x 6.3/4 9/1/2016 5:32:59PM Page 10 COMPASS 5000.1 Build 74 i 9 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W -Shape (°) (°) (usft) (usft) (usft) CD5-07D 01.Heel 041416 JD 0.00 0.00 7,609.20 -7,808.68 9,002.11 -plan hits target center -Circle(radius 100.00) CD5-07D 00.AIpCKO 041916 JD 0.00 0.00 7,522.17 -6,988.09 8,563.04 -plan hits target center -Circle(radius 100.00) CD5-18 Polygon 090116 BP 0.00 0.00 7,701.20 -7,855.86 8,913.93 -plan misses target center by 135.80usft at 15071.88usft MD(7609.45 TVD,-7812.92 N,9004.38 E) -Polygon Point 1 7,701.20 0.00 0.00 Point 2 7,701.20 -10,520.51 5,630.11 Point 3 7,701.20 -10,426.14 5,806.46 Point 4 7,701.20 94.38 176.35 CD5-07D 02.Toe 041416 JD 0.00 0.00 7,701.20 -15,744.43 13,248.97 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") : - 15,067.06 7,609.20 7-5/8"X 9-7/8"by 11" 7-5/8 11 115.30 115.30 20"x 42" 20 42 27,000.00 7,730.33 4-1/2"x 6-3/4" 4-1/2 6-3/4 2,378.95 2,185.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 14,300.04 7,540.20 Alpine C 14,514.95 7,560.20 Alpine B4 15,067.06 7,609.20 AlpineA 1,344.98 1,320.20 Base Permafrost 9/1/2016 5:32:59PM Page 11 COMPASS 5000.1 Build 74 • III SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:CD5-18(7D) Company: ConocoPhillips(Alaska)Inc.-WNS TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Project: Western North Slope MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad North Reference: True Well: Plan:CD5-18(7D) Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD5-18 Design: CD5-18wp06(7D) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,170°TF,for 300.31' 600.31 600.00 -11.62 2.05 Start 2.5°/100'DLS,0°TF,for 690.83' 1,291.14 1,270.20 -165.70 29.22 Hold for 107.68' 1,398.82 1,370.20 -205.04 36.15 Start 3°/100'DLS,-52.34°TF,for 980.13' 2,378.95 2,185.20 -651.25 312.61 Hold for 20' 2,398.95 2,199.15 -661.75 322.35 Start 3°/100'DLS,-31.76°TF,for 634.61' 3,033.56 2,570.21 -996.92 708.37 Hold for 10050.45' 13,084.02 7,202.31 -6,237.89 7,925.54 Start 3°/100'DLS,55.96°TF,for 1048.25' 14,132.26 7,522.17 -6,988.09 8,563.04 Start 2°/100'DLS,0.01°TF,for 117.99' 14,250.25 7,535.57 -7,091.44 8,618.34 Hold for 699.8' 14,950.05 7,600.69 -7,705.79 8,947.05 Start 2°/100'DLS,-0.1°TF,for 117.01' 15,067.06 7,609.20 -7,808.68 9,002.11 Hold for 20' 15,087.06 7,610.25 -7,826.29 9,011.53 Start 3°/100'DLS,0°TF,for 81.02' 15,168.08 7,612.77 -7,897.68 9,049.74 Hold for 8900.16' 24,068.24 7,701.20 -15,744.43 13,248.97 Adjust TF to 0°,for 2931.76' 27,000.00 7,730.33 -18,329.19 14,632.22 TD:27000'MD,7730.33'TVD 9/1/2016 5:32:59PM Page 12 COMPASS 5000.1 Build 74 • II ConocoPhilli s Alaska Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-18 (7D) Plan: CD5-18 CD5-18wp06(7D) Sperry Drilling Services Clearance Summary Anticollision Report I61iw Posk.d 01 September,2016 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-18(70)-Plan:CD5-18-CD5-18wp06(7D) Well Coordinates: Datum Height:Plan:33.9+36.3 @ 70.20usft(Doyon 19) Scan Range:0.00 to 27,000.00 usft.Measured Depth. Scan Radius is 2,896.37 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version:5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services • S ConocoPhillips(Alaska)Inc.-WNS HALLI BU RTO N Western North Slope Anticollision Report for Plan: CD5-18(7D)-CD5-18wp06(7D) Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:CD5 Alpine West Pad-Plan:CD5-18(7D)-Plan:CD5-18-CD5-18wp06(70) Scan Range:0.00 to 27,000.00 usft.Measured Depth. Scan Radius is 2,896.37 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft CD4 Nanuq Pad CD4-321-CD4-321-CD4-321 20,444.47 1,009.85 20,444.47 673.93 19,325.00 3.006 Clearance Factor Pass-Major Risk CD5 Alpine West Pad CD5-07-CD5-07-CDS-07 49.23 220.02 49.23 217.06 50.00 74.328 Centre Distance Pass-Major Risk CD5-07-CD5-07-CD5-07 398.47 221.65 398.47 207.22 400.00 15.365 Clearance Factor Pass-Major Risk CD5-08-CD5-08-CD5-08 399.12 198.84 399.12 184.46 400.00 13.827 Clearance Factor Pass-Major Risk CD5-09-CO5-09-CD5-09 49.31 179.97 49.31 177.01 50.00 60.757 Centre Distance Pass-Major Risk CD5-09-CD5-09-CD5-09 398.44 181.11 398.44 166.65 400.00 12.526 Clearance Factor Pass-Major Risk CD5-10-CD5-10-CD5-10 299.50 159.85 299.50 148.76 300.00 14.402 Centre Distance Pass-Major Risk CD5-10-CD5-10-CD5-10 398.97 160.03 398.97 145.83 400.00 11.266 Clearance Factor Pass-Major Risk CD5-11-CD5-11-CD5-11 274.60 139.47 274.60 129.22 275.00 13.617 Centre Distance Pass-Major Risk CD5-11-CD5-11-CD5-11 399.18 139.89 399.18 125.55 400.00 9.753 Clearance Factor Pass-Major Risk CD5-12-CD5-12-CD5-12 249.99 119.37 249.99 110.09 250.00 12.861 Centre Distance Pass-Major Risk CD5-12-CD5-12-CD5-12 399.65 119.80 399.65 105.37 400.00 8.302 Clearance Factor Pass-Major Risk CD5-21-CD5-21-CD5-21 183.90 60.24 183.90 53.60 175.00 9.075 Centre Distance Pass-Major Risk CD5-21-CD5-21-CD5-21 384.02 60.72 384.02 46.68 375.00 4.326 Clearance Factor Pass-Major Risk CD5-313-CD5-313-CD5-313 722.24 97.67 722.24 86.37 725.00 8.644 Centre Distance Pass-Major Risk CD5-313-CD5-313-CD5-313 796.39 98.49 796.39 85.85 800.00 7.796 Clearance Factor Pass-Major Risk C05-313-CD5-313PB1-CD5-313PB1 722.24 97.67 722.24 86.37 725.00 8.644 Centre Distance Pass-Major Risk CD5-313-CD5-313PB1-CD5-313PB1 3,382.58 111.42 3,362.58 30.74 3,425.00 1.381 Clearance Factor Pass-Major Risk CD5-314-CD5-314-CD5-314 870.53 72.43 870.53 58.85 875.00 5.334 Centre Distance Pass-Major Risk CD5-314-CD5-314-CD5-314 895.10 72.56 895.10 58.55 900.00 5.179 Clearance Factor Pass-Major Risk CD5-315-CD5-315-CD5-315 941.39 56.94 941.39 41.87 950.00 3.778 Centre Distance Pass-Major Risk CD5-315-CD5-315-CD5-315 965.69 57.07 965.69 41.61 975.00 3.692 Clearance Factor Pass-Major Risk CD5-315-CD5-315PB1-CD5-315PB1 941.39 56.94 941.39 41.87 950.00 3.778 Centre Distance Pass-Major Risk CD5-315-CD5-315PB1-CD5-315PB1 965.69 57.07 965.69 41.61 975.00 3.692 Clearance Factor Pass-Major Risk Plan:CD5-17(6D)-Plan:CD5-17-CD5-17wp05.1(6D 299.90 19.81 299.90 8.46 300.00 1.745 Centre Distance Pass-Major Risk Plan:CD5-17(6D)-Plan:CD5-17-CD5-17wp05.1(6D 399.82 20.00 399.82 5.48 400.00 1.377 Clearance Factor Pass-Major Risk 01 September,2016- 1736 Page 2of6 COMPASS • • ConocoPhillips(Alaska)Inc.-WNS HALLI B U RTO N Western North Slope Anticollision Report for Plan: CD5-18(7D)-CD5-18wp06(7D) Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-18(7D)-Plan:CD5-18-CD5-18wp06(7D) Scan Range:0.00 to 27,000.00 usft.Measured Depth. Scan Radius is 2,896.37 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:CD5-17(6D)-Plan:CD5-17L1-CD5-t7L1wp05 299.90 19.81 299.90 8.46 300.00 1.745 Centre Distance Pass-Major Risk Plan:CD5-17(6D)-Plan:CD5-17L1-CD 399.82 20.00 399.82 5.48 400.00 1.377 Clearance Factor Pass-Major Risk Plan:CD5-18(7D)-Plan:CD5-18L1-CD MIMI MEM IIIIIIIIII 11111 1111111111111. MM. 11111111111111111111111 Minor Risked Plan:CD5-19(80,formerly 7D)-Plan:C 400.04 19.95 400.04 5.37 400.00 1.368 Clearance Factor Pass-Major Risk Plan:CD5-19(80,formerly 7D)-Plan:CD5-19-CD5- 425.03 19.93 425.03 6.89 425.00 1.529 Centre Distance Pass-Major Risk Plan:CD5-19(813,formerly 7D)-Plan:CD5-19L1-CD 400.04 19.95 400.04 5.37 400.00 1.368 Clearance Factor Pass-Major Risk Plan:CD5-19(8D,formerly 7D)-Plan:CD5-19L1-CD 425.03 19.93 425.03 6.89 425.00 1.529 Centre Distance Pass-Major Risk Plan:CD5-20-Plan:CD5-20-CD5-20wp03 400.20 39.89 400.20 25.33 400.00 2.739 Clearance Factor Pass-Major Risk Plan:CD5-20-Plan:CD5-20-CD5-20wp03 450.20 39.83 450.20 28.35 450.00 3.471 Centre Distance Pass-Major Risk Plan:CD5-22-Plan:CD5-22-CD5-22wp01 399.92 79.73 399.92 65.16 400.00 5.473 Clearance Factor Pass-Major Risk Plan:CD5-22-Plan:CD5-22-CD5-22wp01 524.99 79.39 524.99 70.61 525.00 9.039 Centre Distance Pass-Major Risk Plan:CD5-314X-Plan:CD5-314X-CD5-314Xwp04 1,288.99 34.72 1,288.99 13.68 1,300.00 1.650 Centre Distance Pass-Major Risk Plan:CD5-314X-Plan:CD5-314X-CD5-314Xwp04 1,313.67 34.72 1,313.67 13.51 1,325.00 1637 Clearance Factor Pass-Major Risk Plan:CD5-314X-Plan:CD5-314XPB1-CD5-314XPB 1,288.99 34.72 1,288.99 13.68 1,300.00 1.650 Centre Distance Pass-Major Risk Plan:CD5-314X-Plan:CD5-314XPB1-CD5-314XPB 1,313.67 34.72 1,313.67 13.51 1,325.00 1.637 Clearance Factor Pass-Major Risk Plan:CD5-316-Plan:CD5-316-CD5-316wp03 919.66 31.08 919.66 16.77 925.00 2.172 Centre Distance Pass-Major Risk Plan:CD5-316-Plan:CD5-316-CD5-316wp03 944.12 31.34 944.12 18.71 950.00 2.142 Clearance Factor Pass-Major Risk Plan:CD5-316-Plan:CD5-316PB1-CD5-316PB1wp0 919.66 31.08 919.66 16.77 925.00 2.172 Centre Distance Pass-Major Risk Plan:CD5-316-Plan:CD5-316PB1-CD5-316PB1wp0 944.12 31.34 944.12 18.71 950.00 2.142 Clearance Factor Pass-Major Risk TD:CD5-06-CD5-06-CD5-06 299.39 238.26 299.39 226.99 300.00 21.135 Centre Distance Pass-Major Risk TD:CD5-06-CD5-06-CD5-06 398.52 239.27 398.52 224.98 400.00 16.749 Clearance Factor Pass-Major Risk TD:CD5-06-CD5-06L1-CD5-06L1 299.39 238.28 299.39 226.99 300.00 21.135 Centre Distance Pass-Major Risk TD:CD5-06-CD5-06L1-CD5-06L1 398.52 239.27 398.52 224.98 400.00 16.749 Clearance Factor Pass-Major Risk 01 September,2016-17:36 Page 3 of 6 COMPASS • • ConocoPhillips(Alaska)Inc.-WNS HALLI B U RTO N Western North S tope Anticollision Report for Plan: CD5-18(7D)-CD5-18wp06(7D) Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 36.30 400.00 CD5-18wp06(7D) INC 36.30 400.00 CD5-18wp06(7D) GYD-GC-SS 400.00 1,400.00 CD5-18wp06(7D) MWD 400.00 2,378.95 CD5-18wp06(7D) MWD+IFR-AK-CAZ-SC 2,378.95 3,878.95 CD5-18wp06(7D) MWD 2,378.95 15,067.06 CD5-18wp06(7D) MWD+IFR-AK-CAZ-SC 15,067.06 16,567.06 CD5-18wp06(7D) MWD 15,067.06 27,000.00 CD5-18wp06(7D) MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 01 September,2016- 17:36 Page 4 of 6 COMPASS • • ]7' September 01 2016 Ladder View CD5-18wp06 (7D) The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. s a JW ......0..A aimenm 0 0 0 0 I�JW 0 0 0 '11 300 — _ ._ I I' II€ r gal = zji jIi I, c 150 VIA 1 i RIr i F111111.101 m olp e� i i OF R '9;11 J . o 1► Ill U . / IP 0 .-3-- 1 i i ; I 1 1 1 I i i I I 1 I 1 I 1 1 I I I 1 ; I I I 1 I I I ', Equivelant Magnetic Distance 4000 8000 12000 16000 20000 24000 Displayed interval could be less than entire well:Measured Depth 36.30 To 27000.00 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 36.30 400.00 CD5-18wp06 (7D) (Plan: CD5-18) INC 115.30 115.30 20"x 42" 36.30 400.00 CD5-18wp06 (7D) (Plan: CD5-18) GYD-GC-SS 2185.20 2378.95 10-3/4" x 13-1/2" 400.00 1400.00 CD5-18wp06 (7D) (Plan: CD5-18) MWD 7609.20 15067.06 7-5/8"X 9-7/8" by 11" 400.00 2378.95 CD5-18wp06 (7D) (Plan: CD5-18) MWD+IFR-AK-CAZ-SC 7730.33 27000.00 4-1/2"x 6-3/4" 2378.95 3878.95 CD5-18wp06 (7D) (Plan: CD5-18) MWD 2378.95 15067.06 CD5-18wp06 (7D) (Plan: CD5-18) MWD+IFR-AK-CAZ-SC 15067.06 16567.06 CD5-18wp06 (7D) (Plan: CD5-18) MWD -1 nR7(IR 27000 00 ('.ns-1Rwn0A(7111 (Plan. ('f '-1R1 M\/VfI+IFR-AK-(:A7-SC 0 > I 8 n t 2 13 3 N m qR QR a x M V N ! M i 0 0 0 0 0 0 0 U U U U U U U . I \\ y 6 �awi�� _ I '� i , a. \\ u) 11111111/t46 III i - ' 1 Pr pig ell.- • 110 0 I , 1 1 1 I I I I 1 I I I 1 1 I I I I I I I I I I I I I I I I I 1 I I 1 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance I • 3b sou CD5-18wp06 (7D) MD Inc Azi TVD Dleg TFace Target 300 .-..__ 490 36.30 0.00 0.00 36.30 0.00 0.00 36.30 To 27000.00 300.00 0.00 0.00 300.00 0.00 0.00 490 670 600.31 4.50 170.00 600.00 1.50 170.00 1291.14 21.78 170.00 1270.20 2.50 0.00 670 860 1398.82 21.78 170.00 1370.20 0.00 0.00 17:39,September 01 2016 2378.95 45.75 137.14 2185.20 3.00 -52.34 860 1040 CASING DETAILS 2398.95 45.75 137.14 2199.15 0.00 0.00 1040 1230 3033.56 62.56 125.99 2570.21 3.00 -31.76 TVD MD Name 13084.02 62.56 125.99 7202.31 0.00 0.00 1230 1410 115.30 115.30 20" x 42" 14132.26 82.30 151.85 7522.17 3.00 55.96 CD5-07D 00.A1pCK0 041916 JD 2185.20 2378.95 10-3/4" x 13-1/2" 14250.25 84.66 151.85 7535.57 2.00 0.01 1410 1600 7609.20 15067.114E/8" X 9-7/8" by 11" 14950.05 84.66 151.85 7600.69 0.00 0.00 7730.33 27000.00 4-1/2" x 6-3/4" 15067.06 87.00 151.85 7609.20 2.00 -0.10 CD5-07D 01.Heel 041416 JD 1600 2660 15087.06 87.00 151.85 7610.25 0.00 0.00 SURVEY MOW 15168.08 89.43 151.85 7612.77 3.00 0.00 2660 3730 .332n Fra 0633KR 7e w��avtPlan 7PP 24068.24 89.43 151.85 7701.20 0.00 0.00 CD5-07D 02.Toe 041416 JD 06.36 6.1.611 C05n6.3366(ml (Plan:0,18) INC 27000.00 89.43 151.85 7730.33 0.00 0.00 3730 4790 36.06 eee Be C05-18.3306(ID) (Plan:6125-18) 0Y0-6C-65 9 C05-18.3306(70) (Plan:C0-181 NW we.ee i 5 C05-18.3366(701 (Plan:005-181 Nw0.1va-AK-CA2-66 4790 5850 2378.95 3878.95 COS-1853366(70) (Plan'.005-18) !M 5067.66 C05-18.3366(70) (Plan:C05-18) M.O•IFR-AK-CAZ-Y 15667.86 16567.66 035-18563.(70) (Plan:05-181 MD 5850 -- " 6910 15667.66 27600.06 06-16.P66(70) (Plan'.COS-18) M...,.-Al(-C... 6910 7970 7970 9040 9040 10100 10100 12210 0/360 12210 14330 s,,, ,',y{ `I " (6D) 14330 16440 30/30 ., r ' "� � }'�� 16440 18550 S'II('si / fviiiir��•/ -1" a,r• ...,_,,,,,,,,,,,47O / * J 18550 20660 is )1„,4 ►e� Ill Lii i II 1--'4, r ilitsiiii �- 20660 22770 4.1 CD5 ` 44 s pagr eteAR \\A/ �* � w - 22770 24890 -ice �. 11 f�'.', 11 y.alAirAt� - f rat:t / 't ' � ' :-...11.‘4,,-11010-,..�' "08 24890 27000 .-0. •1/1J1!'"i' / Vg^4'A��. 61 f r , 4 ,4\S 31::1�s'1'1 • `' mi aibM� 11,1'E\ -- 01,,1'` 1r r�.4/ y ti ttt Yer'Oia�1'. ►f!`1p�kP6 - �� , 7 * , 1 1• a 5-1O `�111�' '�' � ���y ►,��� � ���� m1i�� i .i s�'�� �1 .,.. -60/300 11.0 0+°+ ktif+ . ��� d t `Z .--_,;;:- .----.,-,4„/.� -.409„ 1Otr -� �d\ smi1�n Itis 6----- 'I.r�O '''i, <.._-../ / w � <. 1t���;ilt ..507 �U�►.�C'.yy�rt`� 9M1► w�.�A� ��`�='0" � '-',4b-NN� �1 e' r � r 1 CD5-19 a r t ►,, i _ ' :�:���a,M7iay�a�.k ..,r� CoA Iyra�F fta'�1�'y'4D i-+f 014 Ch`,it, Itcf, Fr'a'/'/ d T.. r Jn'E... fns. $ i i> . ,t ,° = n e 1'S+' x .+ ?',/� r 'mssa� ►/ t ^ '"ate a£ ♦ H '>L��, / `�/CD5-31 ,-�,�& 1► h � , ,,r z -v ./� `�c1u fe:i fK� a as e . ► > ,74.,-40,1*.tt 0.4 111, ?a"t tit a► - i 1*4M N l►�.r a•K! T11 • wNib '" .iaiv`tkk,A•+1t116%r S Qt K j\ r 0•' �°-09rAi ; X111 I I.�� E��r+ tt- a`- _.-4 //'/'114,\N 4 MIC.,111 ,�j�J n�.. r^_'.1 t -90/270 to vwiir_ �`°�LIA.` '.;...i t � ` .j ' 90 6�' a ►A ri I1U ...,,..../- CD5-314 ;t.1a►i::1 1� e 1t � .����•1'/ \ J\ 4 _i -1w;li1P \\ Minor Risked CD5- 1.,Nje04tilif�/' \ \ CD5-18L-wp05.1 (7D) tVe21w0 ' . 90 �� \ 1 0 01A • 120 120/240 /f� �\ /� 120 ,a.Aiiik Impi •', �I�� 150 CD5-3-'0"• Alt, 165 M �'��� 180 ''41i 195 -150/210 210 150 225 -180/180 0 • 17:44,September 01 2016 Easting(6000 usft/in) , IIIIIIII1111liIIIIiiiiIiiiiliiiiIiiiiliiirIIIIII , , , , I , iiiliiiiIiiiiliiilIiiilIiiiiIiiiili iiIiiii - . "we-s it ' CD S95-o9 _ (NOT a Spider) _ CD5-07 — CD1 Alpine P - 002 Alpine Pad — C.•-10 CD5 Alpine West Pad = CO \ lk,OP _ e— -'-• ‘..AO - 0 o - ' -21 -` - rn �— \ —o 0 rn o c _ I I I I I I I b"NNIIIII,k_,.,1 z CD 2wp0 CD5-08 _ = CD4 Nanuq Pad _ _ ( 1 I CD5-315PB1 CD -31 '61 B4-321 - - - CD5-314XPB1w.04 - CD5-316PB1wpI• CO'18L1wp05.1 (7D) CD5-313 CD5-17Wp6605.(6i($D) _ C. 1 s>M 6 IPdD) _ CD5-315 CD5-316wp03 CD5-18wp06(7D) _ CD5-314Xwp04 - M III iIIIIIIIIIIIIIIII , , i , , , IIIIIIi . , 11111111111111111 , , . 1 , , , , I , , , , i , , , , i , , , , i , , , , i , , , , I , , , , I , , , ,- Easting(6000 usft/in) AC Flipbook casing Detail: survey Progam TVD MD Name Depth From Depth TO SurveylPlan TOoI CD5-18wpo6 (7D) 2+8510 x3]8.95 0 0 0"xq1" 36.30 400.00 C05+8wpu5.+(70)(PIxn:C05+8) INC 36 300 +o-3/4x+3-+li 36.30 400.00 C5'+8wp05.+(]0)(PIan:C05'+8) GY6GC-SS ]fio9 i0 ISo6Jo6 )SIB"x 9-lle"by++„ 400.00 +400.00 C05-+8w2051(70)(Plan:C05+8) MWD 2 T0 O+.xo x4068.14 4-+Ii"x6-3/4" 400.00 x3]8.95 CO518wpo51(70)(Plan:C05+8) MWD+IFR-AK-CAZ.SC 36•30 30 ■ 50000 1378.95 5878.95 CD 5+8,vpo5.+( )(Pan:C05+8) MWD 300 490 1378.95 +5067.06 CD5-+8wp05.+(]070)(Plan:005-8) MWD+IFR AK-CAZ SC +5067.06 +6567.06 C05,8,01,,05 I(70)(Plan:CD5.,8) MWD +5067.06 24068.14 CD5,Sop05.+(70)(Plan:CD5,8) MWD+IFR.AK-CAZ--SC 490 670 MD Azi o/36o 67o 86o 36.3o o.o0 90 860 1040 300.00 0.00 -30/330 o 600.31 170.00 8o 1040 1230 1291.14 170.00 '1150 7o 1230 1410 1398.82 170.006o 237895 13714 1410 1600 2398.95 137.14 60/300 601600 2540 3033.56 125"9940 ,iti- '~sk 254o 348o 13084.02 125.990 ---s k3 .7 3480 4410 14132.26 151.85 _14250.25 151.8520 4.4",:i.,„41 .4.-tattg- 4410 5350 14950.05 151.853 -1,� . _ � � 5350 6290 15067.06 151.85 90/270 _ _ 0 90 15087.06 151.85 1' (8D 6290 7220 C 15168.08 151.85 '.' .' i 7 20 7220 8160 24068.24 151.85 CD -2/ t Jr ',- . ill 0 8160 _ _ .9100 40 9100 10970 -120/240 50 120 10970 12840 6o 12840 14710 70 14710 16580 16580 18460 -150/210 80 •0 150 18460 20330 -180/180 20330 22200 22200 24068 13:39,August 31 2016 • • Casing Details Survey Progam _ TVD MD Hame Depth From Depth To Survey/Plan Tool CDS_18wpo6 .D` 8So "5.95 D0"x4x" 36.30 400.00 CD518wpu57(60)(PIanC5+8) INC 36 300 ru / J a+5ao 47e.95 36.30 400.00 CD518wp051(70)(Plan:<057e) 400.00 GYD-GG-SS 760910 'So68 6-518"X 9 JI8"by"" 400.00 ?4o0.Oo CDS-t8wpo5'(]D)(Plan:CDS-'8J MWD 4-+/�x6'314" 378.95 CD5'18wpo5.1(70)(Plan:CD5-18) MWD.IFR-AK-CAZ-SC 77o1.2,7 14068.x4: ------ 500.00 To 1000.00 0378.95 5088.96 CD5'8wpO5,(70)(Plan:(0548) MWD 300 490 0068.86 '6566.06 CDs-'8wpO5.'(6D)(Plan:C05.'8) MWD.IFR- SC-SC +5066.06 16566.06 CDS'8wpo5'(JD)(Plan:CDS-'8) MWD '5066.66 24068.64 CD5.8wp057(]D)(PCa (05,8) MWO.IFR-AK.CAZ-SC 490 670 MD Azi ,, 1,4.^ 670 860 36.30 0.00 CD5pAO./ .1 (6D) 860 1040 300.00 0.00 _ a a tty�� 1 0 600.31 170.00 CD5- O 10j �I► � ae:1% 1040 1230 1291.14 170.00 �1� -``►�j'��:��� 1230 1410 AlaWA1 8.82 170.00 ..�� ..- v i v� •�.�I�� 39 �,�?�1�, �,'4����,- 4�• ,•:� 141° 1600 2378.95 137.14 r:• •iyi b:`'jllw !,. ��O.tia.irA'i p.Aiv'u"•'^11hp -60 00 1•.� �.• ... , ,.4�� ,60 1600 2540 2398.95 137.14 ��. �,►���.q� ����� �.� -. /i, �.1 ,r.�... �.►.. .. ►Vii/ 3 33 5 125 99 i ► -.;I,�. / •'-'00-_-.44'00,'. . , ki.•• r. • .�-� •.moi►. ►� .4".444 2540 3480 13084.02 12 • ��1�,.�.1�J��I�Qt I �I/IIJ�4 i .rI! F / 5.99 ���_��►�� .�i�-.. rrl�,• ... � ..� ::',?'4.11i0,.'� � /1, �O•t Ir�S.1j C u p.00 i . i .1/ 1 . / / 1413x.26 151.85 CD5- i!'.T� .,�•. Y ..,������ ....a. ��,,/ 3480 4410 • ;I,�t Imo.. \►� ♦ . e ♦ •1 r4i701. �fripl it 7147.?4, 0024:��%V.-J..;`- '' . 4410 5350 14250.25 151.85 ��,s1�l��1�P��..♦�....4, ��► Altrat'iv,INN 14950.05 151.85 Iin► !c; -.:,,,,%�-.. i42.2.I ' `t,...,„___.,,,/ 5350 9 15067.06 151.85 -90/270.�.� !SiZ,;, tra L 'W 90 re&E.�i1. I' `.// �/ 6290 220 15087.06 151.85 PIMr.*Oa;� �"., 9 7 15168.08 151.85 tall" �/ 20 7220 8160 24068.24 151.85 � 8160 9100 40 9100 10970 -120/240 50 120 10970 12840 60 12840 14710 70 14710 16580 16580 18460 -150/210 80 150 •0 18460 20330 -180/180 20330 22200 22200 24068 13:43,August 31 2016 • • Casing Details Survey Program ND MD Name Depib From DepfM1 To SurveylPlan Tool CDS-�$Wp06 (7D) o 0 0"xqv" 36.3o 400.00 CD518wpo51(7D)(Plan:CD518) INC 36 300 `J Q ru U 85 v0 8.95 .3...13/v" 6.30 00.00 CDS'8wpo5 (JD)(Plan C05 e) GYD GC 55 7609.20 15067.06 7-5/8"X 9-7(8"by n" 400.00 1400.00 CD5-18wp05.1(70)(Plan:CDS-(8) MWD 7702.20 x4068.24 4-1/2"x6-3/4" 400.00 0378.95 CD5-1800P05.1(70)(Plan:C05-18) MWD.IFR-AKLIZ.SC 1 __._--. 1000.00 To 2�DU.00 x378.95 3868.95 CD518wpa51(70)(Pln:CDS-18) MWD 300 490 x378.95 15066.06 705-18wpo5.1(7)(Plan:C05-18) MWD.IFR-AK{pZ�SC 5067.06 16567.06 CDS-181ryn5.1(70)(Plan:C05'18) MWD - 15067.06 24068.x4 CD5-18wp05.1(70)(Plan:CO5-18) MWD.IFR-AK{AZ-SC 490 670 M D Azi CD5- 1 PB1 67o 86o 36.30 0.00 �/ ramasrf 300.00 0.00 CD5-19L1 ...(1 �4+t',. ►►flOs,!r: o1i�,'�• 860 1040 40, 600.31 170.00 , �'•.;a�+ t`I/�e/,.,#:,./ 7340.......4.4-0.,,,04441,1 , 1040 1230 3 ,. `�0� 04,12, .•w - , s®®v� -314 ®I II/ ®l►ter 1291.14 170.00 '� • .� �i�e�rsv '' 1� 0 ®_�'�- 12 0 1 10 1398.85 170.00 ,®4�s1 4 ' ��� '►`�. jrhllti.- •enVI'e •��-► !1�)�i =� 1410 1600 2378.95 1 1 �Iillea• !ice%0*. ♦ •-•►® 37 95 37. 4 t ii. .,.,i!�•"•� ®'�=,. . - 2398 95 137.14CD 5 ��►a���uI %j4fiii-�i�3/taifi�liftti• "%irt* N• -14W 60 1600 2540 3033.56 125.! D5314 9 ��"ya�°�l��lalPi�!`, �,,-�'. 0-147#5,3104"t�f '� 2540 3480 aite 14'x'iG�/1`U�Q FNfitififi ► r 7 Al 13084.02 125.9D_ s; -- 0,10,5:04,4�0',�il`® R" 6 t- riv'T � -.---_.._,,..,,..�o!j.�►cr+..�e�Ng/ 11 3480 4410 14132.26 15,. ,P50r ►i.�� -®.�����`"-=.-':;'"...--<--- ,�� +" 4410 5350 14950.05 151.85 ► �� '�� �� 0 15067.06 151.85 90/270 5350 6290 9 15087.06 151.85 Mr 6290 7220 15168.08 151.85 20 7220 8160 24068.24 151.85 30 8160 9100 40 9100 -10970 -120/240 50 120 10970 12840 60 12840 14710 7o 14710 1658o 1658o 18460 -150/210 80 150 90 18460 20330 -180/180 20330 22200 22200 24068 13:45,August 31 2016 • • razing Details Survey Program ND MD Name Depth From Depth To Survey/Plan Tool CD5-18wpo6 (7D) o 0 o"x43• 6.30 00.00 CDSIBwpoSl(7D)(PIan:CD518) INC 36 300 i�85�xo x3)8.95 �tr314"x•3�/x" 36.30 400.00 CD5,8wp05.,OD)(Pt..,,05,8) GY6G<SS 7609.20 15067.06 )5/8"09'7)8 by i," 400.00 .00 CD5-+8wpo5.l(7D)(Plan:CD5-i8) MWD To7701.00 x4068.14 4I)0 x6-3/4" 400.00 0378.95 C05'r8wp05.1(7D)(Plan:C05-18) MWD.IFR-AK-CAZ.SC 2000.00 000 00 378.95 3878.95 CDS-18.vp05.1(70)(Plan:CDS'i8) MWD 300 490 1378.95 I5066.06 <DS-t8wpo5I(70)(Plan:CDS-Ie) MWD.IFR.AK-CAZ.SC 15067.06 T6567.06 CD5-111,05.I(7D)(Plan:C05,8) MWD +5067.06 04068.x4 CD5.18wp05.:(70)(PIan:CD5'I8) MWD+IFR-AK-CAZ-SC 490 67o MD Azi 0 /360 67o 86o 36.3o 0.00 90 86o 1040 300.00 0.00 -30/33• 80 ° 600.31 170.00 1040 123o 1291.14 170.00 - 70 1230 1410 1398.82 170.0060 i 1410 16 0 0 2378.95 137.14 Z. •, 2398 95 137.14 -6o/300 / i 50 6o 1600 2540 3033.56 125.99 , ,' / //--- � , , 40 2540 3480 13084.02 125.99 10-0* 30 3480 4410 14132.26 151.85 11011r, , 14250.25 151.85 20 4410 5350 14950.05 151.85i 10 5350 6290 15067.06 151.85 -90/2701 -1 1---' 90 15087.06 151.85 1 i 6290 7220 15168.08 151.85 \ ‘ 2k....!"" 7220-__ 8160 24068.24 151.85 ; \ 0 8160 9100 40 9100 10970 4! 120/240\ 0 50 120 10970 12840 \\ *lit 6o 1284o 14710 00.01 ',kit' 7o 14710 1658o 1658o - 1846o -150/210 8o 150 •0 1846o 20330 -180/180 20330 22200 22200 24068 13:47,August 31 2016 • • casing Details survey Program ND MD Name Depth From DepthSurvey/Plan Tool CD5-18wpo6 (7D) 115(30.3o n5.3o o"xqx" 630 0000 00 CDS tB po5 (70)(Plan:CD5-+8) INC 36 300 7609.30 15067.06 7.5/8"99.7)8"by n" 1+8510 23)8.95 +o-314"x+3-�h 36.30 400.00 <D5•+8wp05.1(]0)(Plan:C05,8) GY6GC 55 400.00 1400.00 GDS'+Bwp05+(]D)(Plan:CD5-+8) MWD ]]0+.x0 34068.34 4-+Ix"x6-3/4" 400.00 3378.95 CD5-o8wpo5.:(70)(Plan:CD5-18) MWDAFR-AK{AZ-SC .._......_._... 4000.00 To 14000.00 2378.95 3878.95 <D5+8wpo5.:(JD)(plan:<D5-+8) MWD 300 490 2368.95 t656J.06 <D505.:OD)(Plan: CD5-18) MWDAPP-AK -5C i5o6J.o6 ifi56J.ob <D5,1,05.:(JD)(Plan:<DS-18) MWD +5067(06 04068.64 CD5+8wp05.+(]D)(Plan:CD5-18) MWD.IFR-0K-CAZ-SC 490 670 MD Azi o /36o 670 86o 36.3o 0.00 90 860 1040 300.00 0.00 -30/33• 80 0 600.31 170.0° 1040- 1230 1291.14 170.007o 1230 1410 1398.82 170.006o 2378.95 137.14 1410 1600 2398.95 137.14 60/fy50 60 1600 2540 303356 125.991308402 125.991413226 151.8514250.25 151.8514950.05 151.85 5350 6290 15067.06 151.85 -90/270 90 15087.06 151.85 ,� 6290 7220 15168.08 151.85 20 7220 8160 24068.24 151.85 0 8160 9100 40 9100 10970 -120/240 50 120 10970 12840 60 12840 14710 7o 1471° 16580 16580 18460 -150/210 8o 150 •0 18460 20330 -180/180 20330 22200 22200 24068 13:51,August 31 2016 • • casing Details Survey Program ND MD Name Depth From Depth To Survey/Plan Tool CD5_18vvpo6 (7D) a 0 0"xqx• 36.30 4ao.oa CDS-18,05A -18) INC 36 300 VVru U 85x0 8.95 o-314x+3112 36.30 ,moo CDS-18wpo51(7D)(Plan:CO6,8) Gy6G<SS l5.30 i5oOS30 400.a0 ',moo COS-18wpo5.1(7D)(Plan:C05'18) MWD 7701.20 04068.34 ,o1/2,6-3/4" 400.00 33]8.95 CD5"18wpo5.l(7D)(Plan:C05-18) MWD•IFR-AK{Ara-S< 3 .._.___--.__... 49 14OOo.00 To15000.00 2378.95 56.6 35 CD5-18wpo5.1OD)(PIar6CDS-18) MWD °° ° 2378.95 15868.06 C05-18wP05.1(70)(Plan:CD5'18) MWD•IFR-AK{Ara-SC 15067.06 16567.86 C05-18wpo5.1(70)(Plan:005.18) MWD 15067.06 24068.24 605-18wp05.1(70)(Plan:CDS-18) MWD•IFR-AK.CAZ-SC 490 67o MD Azi 0/360 670 86o 36.30 0.00 go 86o 1040 3°0.0° o.00 -30/33• o 600.31 170.00 80 1040- 1230 1291.14 170.°0 7o 1230 1410 1398.82 170.°0 6o 1 10 16°0 2378.95 137.14 4 2398.95 137.14 -60/300 5° 6o i600 2540 3033.56 125.99 40 2540 3480 13084.02 125.99 30 3480 4410 14132.26 151.85 14250.25 151.85 20 4410 5350 14950.05 151.85 1.11140,� 5350 6290 15067.06 151.85 go/270 _ g0 15087.°6 151.85iliioi‘a ce 6290 7220 k. 15168.08 151.85 • 7220 8160 24068.24 151.85 • 8160 __ 3100 d -AIIIIIW=, 9,00 10970 -120/240 120 10970 12840 DS- 8L'wP05 (7D) ,2840 1471° 70 14710 16580 1658o 1846o -150/2108o 150 •0 18460 20330 -180/180 20330 22200 22200 24068 13:53,August 31 2016 • • Caning Details Survey Program ND MD Name Depth From Depth To Survey/Plan Tool CD5-18wpo6 (7D) 0 P5.30 0"xqz• 6.30 400.00 CD518wpo51(]D)(Plan CD5-18) INC 36 300 660910 15067.06 7x/8"X 9-J/8"by 1+" i+85.xo x378.95 10.314"%13.1/i" 36.3o 400.00 CD5'18wp05.1 OD)(Plan:C05-18) GVD-GC SS 400.00 t400.00 CD5-+8wpa5�(JD)(Plam CDS-�8) MWD 6) 01.30 14068.14 4-tlx"x fi-3/4° 400.00 378.95 CD5-18v+pu5.1 OD)(Plan:C0568) MWD.IFR-AK-CAZ.SC 15000.00 ■o 22000.00 1378.95 5067.06 CD5t8`po5.1(70)(Plan:CDS+B) MWD 300 490 ]368.95 M56].06 CD5'18wpo5.1 OD)(Plan: 0666) MWD.IFR-AK{AI-S< 15067.06 16567.06 CD5-18.Wa5.1(]D)(Plan:C0518) MWD +5064.06 04068.04 CD5-18wp05.1(70)(PIan:CO5.8) MWD.IFR-AK.CAZ-SC 490 67o MD Azi o /36o 67o 86o 36.30 0.00 90 860 1040 300.00 0.00 ,30 80 0 600.31 170.00 1040 1230 1291.14 170.007o 1230 1410 1398.82 170.006o 2378.95 137.14 1410 1600 2398.95 137.14 -60/30050 60 1600 2540 3033.56 125.992540 3480 13084.02 125.993o 3480 4410 14132.26 151.85 14250.25 151.8520 4410 5350 14950.05 151.85 � 5350 6290 15067.06 151.85 -90/270 90 15087.06 151.85I 6290 7220 15168.08 151.8520 7220 8160 24068.24 151.85 08160 9100 409100 10970 -120/‘‘," 60 ,. .y�.�r12010970 12840 �- 1284° 14710 ILCD5-1etiwpo5 (7D) 14710 16580 16580 18460 80 150 •0 18460 20330 -180/180 20330 22200 22200 24068 13:56,August 31 2016 • • Casing Details Survey❑rogrem ND MD Name Depth From Depth To Survey/Plan Tool CD5-18wpo6 (7D) 30 0 o"xqz" 36.30 4ao.o0 CD518wpo6(7D)(%dn:CD 518) INC 36 300 1+85x0 x3)8.95 �o-314"x+3-i/x" 36.30 400.00 CDS-�ewpo6(70)(Plan:CD5-18) Gy6GC-SS 7609.2o 15067.06 7-518"%9-7/8"by 11" 400.00 raoo. C05�8wpo6(70)(Plan:CDS-�2) MWD x7000.00 q-t/z"x6-314" 400.00 2378.95 C05-18wpo6(70)(Plan:CDS-:8) MWD+IFP.AK{AZSC ...._.. 7730.33 2378.95 3878.95 CD5-18,006(70)(%an:CD5,8) MWD 300 ._......__._._ 490 22000.00 To 27000.002378.95 15067-.6 CD5-,8w0a6OD)Olen:CD5-18) MWD+IFR AK{q1 SC i5067.06 16567.o6 CD5,8wpo6(7D)(Plan:<D5-18) MWD +5067.06 27000.00 CD5-I8wp 06(7D)(Plan:CDS-18) MWD+IF13-06-CAZ-SC 490 670 MD Azi o /360 67o 86o 36.30 0.00 90 86o 1040 300.00 0.00 -30/33. 80 0 600.31 170.00 1040 123o 1291.14 170.0o 7o 1230 - 1410 1398.82 170.0o 6o 2378.95 137.14 1410 1600 2398.95 137.14 6o/300 50 6o 1600 2660 3033.56 125.99 40 266o 3730 13084.02 125.99 0 14132.26 151.85 3 3730 4790 14250.25 151.85 20 4790 5850 14950.05 151.85 ,� 585o 6910 15067.06 151.85 -90/270 � 90 15087.06 151.85 6910 7970 15168.08 151.85 20 7970 _ 904o 24068.24 151.85 0 _______.10100 27000.00 151.85 0 90 4 10100 - 12210 -120/240 ,40 50 120 12210 14330 6o 14330 1644o 7o 1644o 1855o 1855o 20660 -150/210 80 150 •0 20660 22770 -180/18o 22770 24890 24890 27000 17:42,September 01 2016 • 0 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-18 (7D) Plan: CD5-18 Plan: CD5-18wp06 (7D) Error Ellipse Survey Report 01 September, 2016 I • SLB Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-18(7D) Project: Western North Slope TVD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:33.9+36.3 @ 70.20usft(Doyon 19) Well: Plan:CD5-18(7D) North Reference: True Wellbore: Plan:CD5-18 Survey Calculation Method: Minimum Curvature Design: CD5-18wp06(7D) Output errors are at 1.00 sigma Database: EDM Production Survey Tool Program Date 9/1/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 36.30 400.00 CD5-18wp06(7D)(Plan:CD5-18) INC Inclinometer(Totco/Teledrift) 36.30 400.00 CD5-18wp06(7D)(Plan:CD5-18) GYD-GC-SS Gyrodata gyro single shots 400.00 1,400.00 CD5-18wp06(7D)(Plan:CD5-18) MWD MWD-Standard 400.00 2,378.95 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZ SCC 2,378.95 3,878.95 CD5-18wp06(7D)(Plan:CD5-18) MWD MWD-Standard 2,378.95 15,067.06 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15,067.06 16,567.06 CD5-18wp06(7D)(Plan:CD5-18) MWD MWD-Standard 15,067.06 27,000.00 CD5-18wp06(7D)(Plan:CD5-18) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ' Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (0) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) 7) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 115.30 0.00 0.00 115.30 1.61 0.00 1.61 0.00 1.15 0.00 0.00 1.81 1.61 0.00 INC(1,1) 300.00 0.00 0.00 300.00 2.85 0.00 2.65 0.00 1.15 0.01 0.01 2.85 2.65 0.00 INC(1,1) 600.31 4.50 170.00 800.00 0.47 0.00 0.49 0.00 1.15 0.04 0.04 0.49 0.48 173.11 MWD(2,2) 1,291.14 21.78 170.00 1,270.20 1.17 -0.03 2.71 0.11 1.14 0.20 0.23 2.71 1.24 170.72 MIND(2,2) 1,344.98 21.78 170.00 1,320.20 1.34 -0.03 3.31 0.15 1.15 0.23 0.28 3.31 1.39 170.66 MWD(2,2) 1,398.82 21.78 170.00 1,370.20 1.34 -0.03 3.31 0.15 1.15 0.23 0.28 3.31 1.39 170.66 MIND(2,2) 2,378.95 45.75 137.14 2,185.20 2.35 -0.22 4.68 0.17 1.30 0.58 0.67 4.91 2.27 157.13 MWD(3,3) 2,398.95 45.75 137.14 2,199.15 2.36 -0.22 4.79 0.22 1.29 0.59 0.69 5.01 2.29 156.50 MIND(3,3) 3,033.56 62.56 125.99 2,570.21 2.99 -0.55 11.51 2.48 2.06 0.78 2.62 11.72 3.05 137.43 MWD(3,3) 13,084.02 62.56 125.99 7,202.31 18.29 -0.45 83.78 0.15 16.14 8.08 12.34 63.82 9.31 127.93 MWD+IFR-AK-CAZ-SC(4,3) 14,132.26 82.30 151.85 7,522.17 18.65 -5.03 82.62 -4.89 17.83 8.59 13.88 88.00 9.90 128.66 MWD+IFR-AK-CAZ-SC(4,3) 14,250.25 84.66 151.85 7,535.57 18.56 -5.52 63.15 -4.89 18.03 8.61 14.00 68.48 9.93 128.84 MWD+IFR-AK-CAZ-0C(4,3) 14,300.04 84.66 151.85 7,540.20 18.64 -5.52 63.40 -4.89 18.12 6.81 14.05 68.71 9.95 128.92 MWD+IFR-AK-CAZ-SC(4,3) 14,514.95 84.68 151.85 7,560.20 19.15 -5.52 84.88 -4.89 18.63 6.64 14.36 70.07 10.03 129.41 MWD+IFR-AK-CAZ-SC(4,3) 14,950.05 84.66 151.85 7,600.69 19.75 -5.52 66.62 -4.89 19.23 6.68 14.72 71.68 10.14 129.96 MWD+IFR-AK-CAZ-SC(4,3) 15,067.06 87.00 151.85 7,609.20 19.70 -6.04 67.20 -4.89 19.43 6.69 14.83 72.22 10.17 130.14 MWD(4,4) 15,087.06 87.00 151.85 7,610.25 19.72 -8.04 67.31 -4.85 19.43 6.69 14.84 72.34 10.26 130.12 MWD(4,4) 15,168.08 89.43 151.85 7,612.77 19.49 -6.57 67.84 -4.51 19.43 6.70 14.81 72.83 10.30 130.28 MWD(4,4) 24,068.24 89.43 151.85 7,701.20 25.28 -8.57 97.32 -4.89 25.24 6.79 23.29 99.97 17.48 138.41 MWD+IFR-AK-CAZ-0C(5,4) 27,000.00 89.43 151.85 7,730.33 28.92 -6.57 110.70 -4.89 28.88 6.82 26.24 112.74 19.51 140.75 MWD+IFR-AK-CAZ-SC(5,4) 9/1/2016 5:49:46PM Page 2 COMPASS 5000.1 Build 74 Pool Report • 0 CD5-18w•06 Surface Location CZ} CPA: Coordinate Con ,-„1._,=,-. '"--''s,. - � I Tu 1,: 1 t .. From: To: Datum: 1NAD83 .1 Region: lalaska Datum: 1NAD27 Region: lalaska i-- Latitude/Longitude Decimal Degrees _71r Latitude/Longitude ,Decimal Degrees J ; C UTM Zone: r r- South C UTM Zone: !True I— South 6' State Plane Zone: 4 ! Units: bus-it J i+ State Plane Zone: 14 . Units: 1u,-ft _.,11. C Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 1489245.23 X: 1 349212.079158373 Y 15965589/9 Y: 15965823.83088891 Transform 1.1 Quit I Help CD5-18wp06 Surface Location From: _.To: Datum: INAD83 J Region: lalaska j Datum: NAD27 ,t Region: 1alaska— J Latitude/Longitude Decimal Degrees zi 1 Latitude/Longitude !Decimal Degrees (_- UTM Zone: r- South C` UTM Zone: True r South (. State Plane Zone: 4 21.1. Units: us-it +J + - State Plane Zone: 11---- , Units: lus-ft Legal Description(NAD27 only) a Legal Description[NAD27 only) Starting Coordinates: -Legal Description X: 11489245.23 Township: r— oil N Range: 1004 If-Er { Y: 15965569.79 Meridian: lu Section:J1$ IFNL .J 1391.05616 IFEL j 12765.6777 Transform Quit I Help • • ICD5-18wp06 Surface Casing In CPA:Coordinate Convert.,d L i i From: To: Datum: NAD83 Region: l I ska 2,.1 Datum: jNAD27 J Region: (alaska I LatitudelLongitude Decimal Degrees C Latitude/Longitude (Decimal Degrees 21 UTM Zone: V r South r- UTM Zone: 1True r South State Plane Zone: 14 2,.1 Units: (us-ft 6 State Plane Zone: 4 Units: us-ft Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 1489544.63 X: j 349511.456275785 Y: 15964912.43 Y: 1 5965166.45727174 Transform I Quit I Help �CD5-18wp06 Surface Casing r I _ en CPA:Coordinate Converter ` Ism mo From: _.. —To: Datum: INAD83 J Region: (alaska J Datum: 1NAD27 j Region: (alaska C Latitude/Longitude Decimal Degrees J C Latitude/Longitude !Decimal Degrees ' C UTM Zone:I-- r South C UTM Zone: 1True r South r: State Plane Zone: l4 J Units: lus-ft j r- State Plane Zone: 14 J Units: lus-ft J Legal Description[NAD27 only] Com' Legal Description(NAD27 only] Starting Coordinates: Legal Description X: 1489544.63 Township: 011 IN Range: 1004 E Y: 15964912.43I Meridian: IL Section:I18 IFNL 11042.3413 FrIllE, 12455.6723 I Transform , Quit 1 Help 1 s • ICD5-18wp06 Top of Production 1 efi CPA,COOP'dlrlate •,e. -„ar. z s.` � �� ��� r�� From: -To:- Datum: INAD83 J Region: lalaska J Datum: N4D27 Region: lalaska J Latitude/Longitude Decimal Degrees r Latitude/Longitude i Decimal Degrees J UTM Zone: I L- South r UTM Zone: True i South State Plane Zone: �] Units: lus-ft j (: State Plane Zone: (4 Units: lus-ft j Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: -Ending Coordinates: X: 11498087.64 X: j 358054.267023607 Y: 5957582.04 Y: 15957835.74227157 Transform Quit I Help ( CD5-18wp06 Top of Production CPA: �. _ o X en CPA: oo dinate Conn a!; From: __ To: Datum: INAD83_. 71 Region: lalaska j Datum: NAD27 .� Region: lalaska J Latitude/Longitude !Decimal Degrees j C Latitude/Longitude !Decimal Degrees w `' UTM Zone: _...._.__.__. r South C UTM Zone: True r South JP State Plane Zone: 4 Units: Ius-ft xi C State Plane Zone: T-7, Units: Jus-ft 7..i r Legal Description(NAD27 only) C:- Legal Description(NAD27 only) Starting Coordinates:-- --Legal Description X: 11498087.64 Township: 1011 IN Range: 1004 F-71. I Y: 15957582.04 Meridian: U j Section:121 FNL j 12925.9786 IFEL i- 14354.5448 Transform Quit 1 Help • • ICD5-18wp06 Intermediate Casing I ez cPA: Coo-climate Canoe t. :" :- From: To: i i Datum: 1NAD83 Region: ,alaska _I Datum: (NAD27 .j Region: (alaska J Latitude/Longitude (Decimal Degrees J C Latitude/Longitude Decimal Degrees a" UTM Zone: r- South C UTM Zone: True (— South r ,4 State Plane Zone: 14 _,; Units: Ius-ft .....:1 f+' State Plane Zone: 1,-1- 4LidUnits: us-ft Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 1498087.64 X: 358054.287023607 Y: 15957582.04 Y: '5957835.74227157 • • Transform Quit Help ICD5-18wp06 Intermediate Casing I in - ,c l o ZS . CCPA: �u Coo-di anv From: To: Datum: INAD83 Region: lalaska j Datum: 1NAD27 Region: alaska X11 Latitude/Longitude !Decimal Degrees J C Latitude/Longitude 'Decimal Degrees w UTM Zone: 1 r South C UTM Zone: True (- South l State Plane Zone: 171---- Units: 'us-ft ' J C State Plane Zone: 14 J Units: us-ft .. C Legal Description lr`IAD27 only) c Legal Description(NAD27 only) Starting Coordinates: Legal Description - X: 11498087.64 Township: 1011 IN Range: 004 IE J Y: (5957582.04 Merid — ian: 1"-,- Section:121 FNL j 12925.9786 'FEL j '4354.5448 Transform Quit I Help 4 0 • CD5-18wp06 TD In CPA:Coordinate Con.111111.1111.11111111111M— `_'' I LE:11 I' ' ' '' From: r To: Datum: 1NAD83 .j Region: lalaska ..'1 Datum: 1NAD27 Region: alaska J Latitude/Longitude [Decimal Degrees J C Latitude/Longitude rpecimal Degrees ..1 UTM Zone: I r South C` UTM Zone: (True I— South c: State Plane Zone: 14 _j Units: lus-ft J a: State Plane Zone: 14 T Units: us-ft Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: - Ending Coordinates: X: 11503504.39 X: 1 363470.557505166 Y: 15946951.09 Y: +5947204.48979872 1 Transform II Quit I Help I l CD5-18wp06 TD CPA Coordinate Converter I . ,- I I,� 1K, i°-"". . From: To: Datum: iNAD83 ! Region: alaska r Datum: NAD27 A Region I alaska Latitudei'Lon nude 9 IDecimal Degrees C Latitude/Longitude 'Decimal Degrees . UTM Zone: 1 IT South r UTM Zone: (True f_ South ri. State Plane Zone: 14 .r 1 Units: us-ft C State Plane Zone: 1.4 Units: lus-ft A C` Legal Description INAD2F7 only) i+ Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1503504.39 1 Township: loll N Range: )004 E Y: 5946951.09 Meridian: F-----7,1 '3ection:134 1-FA-11- -,-212895.9984 FEL 14046.3413 Transform i Quit I Help • 0 WELLBORE TARGET DETAILS(NAP CO-ORDINATES) 14:30,August 31 2016 w CD5-18wp05e1 (7D) Name TShape CD5-07D Heel 0O 041916 JD ]522.17 Circle(Ramus:100.00) CDSO]0Si 01.Heel 041416 JO ]609.20 Circle(Re0Ns:100.00) Quarter Mile View CD5.0]00131e0411 JO 7701 20 Circee(adiuS 320.00) CD5.0]001.Tee141418 JO Circle]609.20 Circle(Radius:1320.00) CD50]D 02 Toe 041116 JO CIrGe ]]01.20 CirCle(RaOiva'.1320.00) 00618 Pclypon 083116 8P 0.00 Polygon V— 1 Cr ' \ - a n orbG0536 G. G`') ♦ Ga10\ 516 -5000—..____ .........._ co.._ N boa•-_. ......_. 043, 06 11 n GO GO O5 a I '0 G v `1 �-'. CD4-319 7500— i...... C \• 6pI 1 CD4-318A G01• °10000 I_....... ....... ^Q-3, ..._._.... ' _ oati, e N CD5-3 6P 4 1 C M� ati5 G GO 15'1 - `I X12500 .... I „or GoA9� -, A*-. G 0 . t x\11 . 5Q0 Oai 15000 f... ...... ..... G. COS-3%3 \ Oy16 GO*. CD4.91 -17500 Qa ,p , 5 qtw'h' 2500 5000 7500 10000 12500 15000 17500 20000 22500 West(-1/East(+1 (2500 usft/inl 410 S WELLBORE TARGET DETAILS(MAP CO-ORDINATES( 14:27,August 31 2016 CD5-18wp05.1 (7D) NameTVD Shape C05-07D 0.AloCK0 041916 JD 7522.17 Circle(Radius:10.00) CD5-07D 01.Hee1041416 JD 760930 Circle(Radius:10.0) Quarter Mile View CD5-07D 02.Tce 0.11416) 760920 Circle(Radius, 320 0) • CD5-07D 41416 D Circle 770110 Circle(RRai iu 1100.0) C05-07D 02 roe 041416 JO Circle 710120 Circle(Radius,1320.00) C05-18 Polygon 063116 BP 0.00 Polygon • • God 06� \ 1 , -5000 to 16 1 0 -7500 cn \ : Q10000 i �.. N Cps-315PB1 1131 + j t 012500 2 i_. .. ...... . . is i o 15000 ......... p5.__._......_.__..._ 4i3 t[ 17500 .__.... — , ,,,,,,,to___ I 1 i— - I 1 I 2500 5000 7500 10000 12500 15000 17500 20000 22500 West(-1/East(+) (2500 usft/inl • s WELLBORE TARGET DETAILS(MAP CO-ORDINATES) 14:39,August 312016 — CD5-18wpO5.1 (7D) Nam` 75200.0) 005-070 20.ApCKO W 1916 JD 7523.17 Circle(Radius:,00.00) C06.07001.Hee1041416 JO 7609.20 Cade(Radus:,20.00) Quarter Mile View 005-070 02.Toe 041416 JD 7701.20 Clod.ode)(Radius:100.00) 005-07001.H0e 1116 JD Circle 7609.20 Circle,Radius:1320.00) 005-070 02.1 041416 JD Circle 7701.20 Circle(Radius'.1320.00) CO5-16 Polygon 063116 BP 0.00 Polygon I I Q8 -5000-.. j \,,,z). ......_ 1 Y 7500 { ......... o .910000 .......... �3Q�a N G5 + I -C 1 t 212500 {\ i ... ........ \4: , 1 1 5101 -15000—.__... �... I_ 1` e . 05'313 ` 0518 1 1 1 -17500_ 2500 5000 7500 10000 12500 15000 17500 20000 22500 West(-1/East(+1 (2500 usft/inl • CD5-18wp05.1 (7D) Section View 7200 7350— - co to o Alpine C U 0 o Alpine B4 6 _ C 07500— co AlpineA 0 0 TO Ln a ,' Cl. U ----o ^=0 > o o 0 N �, 0 00 00 ' U = �._ U Co.- 0 o--------0- 0 a) 0 0 0 ' i co N 0 0 0 CD),, 7650— `; N M CID 7-5/8"X 9-7/8" by 11" N Qom^ 4-1/2"x 6-3/4" 7800— Ohn'� CD4-321 I --I-- I I I I I I I I 9000 10500 12000 13500 15000 16500 18000 19500 21000 Vertical Section at 152.00° • • CD5-18wp05.1 (70) 3-D View N Alpine B4C�( Alpine A - I ® 055 19wp05.1 I]D • i CD5-18wp05.1 (70) 3-D View G1)S-18woC5 1 CD d IMIS-.-......."'.....s.s.:*........ ..414.1%****4.444444,486.. . GD5-313PB -/ -.41.441,4441;....0 .. AIF neA Alpine B4 G • • Tollerable Collision Risk Worksheet As - built 0 0 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/24/15 CZ DB C.A. UPDATED PER K150003ACS 2 5/2/16 CZ GD C.A. UPDATED PER K160003ACS ALPINE SATELLITE DEVELOPMENT _� LOCATION OF Mir ' i; `'- ' Imo! a THIS SURVEY T12 r, . 7 if . �5 T11N , '�— , `'� 1 CD4 TO ALPINE s ( D2 t� CD5 .04°' ACCESS ROAD g."- fr.71191Po --." ; :.tk CD5 ! p Py �.PA'+1' nn �" PR*, _ �, r ` D ALL IT �� CD1 •�iP�" `a• �r b # ,I( __ 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 SNO��pER OF pPp oeQQ2adoa PAD SSG �c oa� \ \ x 0 p� 00 Oa )00 ,..,,,,,-,),,,,,,(3,„,i, , 0 \pa X o��•.0::::: OO OOCpOVcP \ �".'i `+N••t1 - OO U`(PxX, NP��:�;• - W W i O D•t• PLANT N N 0 0 N OTE: 15.40 52" i -Q(-51 CONDUCTOR CD5-x14 WAS PLUGGED AND n p ABANDONED APRIL 2016. Z37 -- KUUKPIK z UMIAQ I rn ALPINE SURVEY OFFICE PHONE:907-670-4739 `v ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. DRAWING NO: I PART: REV: 15-03-02-1 04/18/2015 CE-CD50-1025 1 OF 3 1 2 • REV, DATE BY CK APP DESCRIPTION REV DATE BY CK APP _ DESCRIPTION 1 4/24/15 CZ DB C.A. UPDATED PER K150003ACS 2 5/2/16 CZ GD C.A. UPDATED PER K160003ACS 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-x99 5,965,666.90 1,489,591.67 70' 18' 49.211" 151' 13' 20.820" 287' 2508' 27.5 33.9 CD5-x01 5,965,661.64 1,489,572.44 70' 18' 49.155" 151' 13' 21.378" 293' 2489' 27.6 34.1 CD5-x02 5,965,656.28 1,489,553.29 70' 18' 49.099" 151' 13' 21.934" 299' 2470' 28.1 34.1 CD5-x03 5,965,650.92 1,489,534.00 70' 18' 49.042" 15V 13' 22.493" 305' 2451' 28.4 34.1 CD5-x04 5,965,645.24 1,489,514.77 70' 18' 48.982" 151' 13' 23.051" 311' 2432' 26.6 34.2 CD5-x05 5,965,639.80 1,489,495.46 70' 18' 48.925" 151' 13' 23.611" 316' 2412' 28.1 34.3 CD5-x06 5,965,634.56 1,489,476.20 70' 18' 48.870" 151' 13' 24.170" 322' 2393' 27.7 34.3 CD5-x07 5,965,629.08 1,489,457.08 70' 18' 48.812" 151' 13' 24.724" 328' 2374' 27.9 34.3 CD5-x08 5,965,623.88 1,489,437.69 70' 18' 48.757" 151' 13' 25.287" 334' 2355' 28.1 34.3 CD5-x09 5,965,618.27 1,489,418.53 70' 18' 48.698" 151' 13' 25.842" 340' 2336' 27.3 34.2 CD5-x10 5,965,613.12 1,489,399.13 70' 18' 48.644" 151' 13' 26.405" 345' 2317' 28.1 34.1 CD5-x11 5,965,607.66 1,489,379.86 70' 18' 48.586" 151' 13' 26.964" 351' 2297' 27.9 34.1 CD5-x12 5,965,602.23 1,489,360.56 70' 18' 48.529" 151' 13' 27.524" 357' 2278' 28.0 34.1 CD5-x13 5,965,596.59 1,489,341.43 70' 18' 48.470" 151' 13' 28.079" 363' 2259' 26.1 34.2 CD5 x14 -5796.5,-594-3E 1,489,322.33 70' 18' 48.414" 151' 13' 28.033" 368' 2240' 27.0 34.2 CD5-14X 5,965,589.94 1,489,317.35 70' 18' 48.400" 151' 13' 28.777" 370' 2235' 27.5 33.8 CD5-x15 5,965,586.10 1,489,303.11 70' 18' 48.359" 151' 13' 29.190" 373' 2221' 26.8 34.2 CD5-x16 5,965,580.48 1,489,283.58 70' 18' 48.300" 151' 13' 29.757" 380' 2202' 27.6 34.0 CD5-x17 5,965,575.11 1,489,264.31 70' 18' 48.243" 15V 13' 30.316" 386' 2183' 27.7 34.0 I CD5-x18 5,96556Y./9 1,48Y,245.23 ICY 18 48.181 151' 1S' SU.8b� 391 21b4 2/-/ 55.9 I CD5-x19 5,96564.42 1,489,225.90 70' 18" 48.131"" 151' 13" 31.430"" 39T 2144" 28.0 33.9 CD5-x20 5,965,558.96 1,489,206.70 70' 18' 48.073" 151' 13' 31.987" 403' 2125' 25.8 33.8 CD5-x21 5,965,553.51 1,489,187.22 70' 18' 48.016" 151' 13' 32.552" 409' 2106' 27.8 33.8 CD5-x22 5,965,548.14 1,489,168.15 70' 18' 47.959" 151' 13' 33.105" 415' 2087' 27.7 33.7 CD5-x23 5,965,542.72 1,489,148.81 70' 18' 47.902" 15V 13' 33.666" 420' 2068' 26.4 33.7 CD5-x24 5,965,537.42 1,489,129.64 70' 18' 47.846" 151' 13' 34.222" 426' 2049' 28.0 33.7 CD5-x25 5,965,532.01 1,489,110.28 70' 18' 47.789" 15V 13' 34.783" 432' 2029' 27.7 33.7 CD5-x26 5,965,526.59 1,489,091.09 70' 18' 47.732" 151' 13' 35.340" 438' 2010' 26.3 33.7 CD5-x27 5,965,521.20 1,489,071.88 70' 18' 47.675" 151' 13' 35.897" 444' 1991' 27.5 33.7 CD5-x28 5,965,515.81 1,489,052.48 70' 18' 47.618" 15V 13' 36.460" 449' 1972' 27.4 33.6 CD5-x29 5,965,510.40 1,489,033.34 70' 18' 47.561" 151' 13' 37.015" 455' 1953' 27.6 33.6 CD5-x30 5,965,504.97 1,489,014.02 70' 18' 47.504" 151' 13' 37.575" 461' 1934' 25.3 33.6 CD5-x31 5,965,499.57 1,489,994.73 70' 18' 47.447" 151' 13' 38.135" 467' 1915' 26.6 33.6 CD5-x32 5,965,494.13 1,488,975.45 70' 18' 47.390" 151' 13' 38.694" 473' 1895' 26.8 33.6 CD5-x33 5,965,488.75 1,488,956.35 70' 18' 47.333" 151' 13' 39.248" 478' 1876' 27.0 33.6 NAD 83 NOTES 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL KUUKPIK (B.P.M.S.L.) UIV1IAQ 3. CONDUCTOR CD5-x14 WAS PLUGGED AND ABANDONED APRIL, 2016. ALPINE SURVEY OFFICE PHONE:907-670-4739 ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 15-03-02-1 04/18/2015 CE-CD50-1025 1 of 3 2 • S REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/24/15 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; CD5-X21, 2/29/16, FB 2016-03, PG. 59; CD5-X16, CD5-X17, CD5-X22, 3/4/16, FB 2016-03, PG. 69; CD5-X18, CD5-X19 & CD5-X20, 3/5/16, FB 2016-03, PG. 75; CD5-X23, CD5-X24, 3/11/16, FB2016-05, PG. 30; CD5-X25, CD5-X26, 3/12/16, FB2016-05, PGS 34-35; CD5-27 THRU CD5-30, FB 2016-05, PGS 38-39, 3/13/16; CD5-X30 THRU CD5-X33, 03/15/16, FB 2016-05, PG. 53. SURVEYOR'S CERTIFICATE I SED OFALA * TO PRACTICE TICE Y CERTIFY D TSURVEYING HAT I AM PROPERLY NHESTATE REGISTERED OF ALASKA, THATTHIS ��� P,..•••••••••••...Sir ♦♦ AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT �� `?.•0.• .'. 1 SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST i ��� ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE *�49th .11'N * •/ CORRECT. • DATE: REGISTRATION NO. LS-5077 • / • /• R, Donald G. Bruce o ♦ s°• No. LS-5077 /EAT ♦��eo PRo............0 p KUUKPIK FESS I ONAL UM I II Q rs ALPINE SURVEY 01-1-ICE PI ZONE:907-670-4739 ALPINE MODULE:C050 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 15-03-02-1 04-18-2015 CE-CD50-1025 1 OF 3 2 • • Häagen Dazs Necessary Plan Request (NPR) • • Initiated by: Jenny Doherty Date: I 04/14/16 Contact Information: 9072634749 Need by:111 04122116 12,E for Event: FEL2 Well Name CD5-18 Placeholder Well Name: CD5-07D A Lateral Last Plan Number(prior to this change request):wp 04 As-built available?No Planned Slot/Surface Location: 18 Y/N: Northing X/E: Fasting 7: above MSL NAD: 83 Rig:Doyon 19 Doyon 19 Air Gap: 36.3 Inclination Profile Horizontal Pilot Hole?: No Laterals?: Dual Lat New Hole from:Surface Number of Hole Sections: 3 Strings CI C 20 X 42 116.30 ND Formations Depths M-Motor Base Permafrost 1250.00 TVOss Max Dogleg: Alpine C 7470.00 NDss 5.0 Limit Steering in this Hole Section?: No Alpine B4 7490.00 wow S S Alpine A 7539.00 Noss u r r f f a a c c e e 10 3/4 x 13 1/2 2t15o0 TVDSS RS-Rotary Pump Tangent: No Max Dogleg: 3.5 Limit Steering in this Hole Section?: No Top of Pool/Production Interval: Name MD/TVD Depth Type Bottom of Pool/Production Interval: Name MD/TVD Depth Type 75/8 x Other 7539.00 TVDSS 87° Targets Y/North X/East Z/Depth Cl-Radius Inc° RS-Rotary: s tin art Alpine C KO 5958411.12 1497685.27 7451.99 TVDSS 100 ft 81 °_ Max Dogleg: Alp C Heel 5958219.59 1497758.89 7466.68 TVDSS 100 ft 90 3.5 Horizontal By: MDRVO Depth Type 90° Alp A Heel 5957582.04 1498087.64 -7539.00 TVDSS 100 ft 87 ° Lineup with Toe at Heel? Yes Alp A Toe 5949562.98 1502173.58 -7831.00 TVDSS 100 ft _ I Ii Bottom Hardline: Kingak MD/TVD Depth Type 90° i I __-- --.-.- --__-; 41/2 x 6 3/4 I Approved by: Greg Hobbs Date: 1 04/14/16 Contact Information: 907-263-4749 Geology/Reservoir Contacts:Jenny Doherty Drilling/Completion Contacts:Greg Hobbs Well Planning Contacts:First&Last Name(s) 04/19/16 11:36 AM hobbsgs The Path to the A Heel Point must pass through the C Heel Point X/Y noted above. 04/25/16 12:22 PM potnibp The X.Y coordinates for the Alpine C Heel were the same as for the Alpine A Heel.Updated them to be the same as they were in CD5-19L2wp03(7D). • • Well: CRU CD5-18 <==Data Input Name: V Loepp <==Data Input NIP Mud Weight(ppg) 9.60 <_=Data Input _ .Weak point or LOT-Measured depth(ft) 2,379' <_=Data Input Weak point or LOT True vertical depth(ft) 2,185' <_=Data Input Weak point or LOT-Hole angle(deg) 45.8° <==Data Input Weak point or LOT-Hole size(in) 13.500" <==Data Input Weak point pressure or LOT-EMW(ppg) 14.00 <==Data Input Zone of interest-Measured depth(ft) 14,132' <==Data Input Zone of interest-True vertical depth (ft) 7,522' <==Data Input Zone of interest-Hole angle(deg) 85.0° <==Data Input Zone of interest-Hole size(in) 9.875" <==Data Input Zone of interest-Pore pressure EMW(ppg) 9.10 <==Data Input liri Gas gradient(psi/ft) 0.10 <==Data Input Bottom hole assembly OD(in) 8.0" <==Data Input Bottom hole assembly length(ft) 200' <==Data Input Drill pipe OD(in) 5.500" <==Data Input BHA annular vol.@ zone of interest(bbl/ft) 0.0326 , DP annular vol.®zone of interest (bbl/ft) 0.0653 DP annular vol. •/ weak •oint bbl/ft 0.1477 Additional safety margin(psi) 0.00 <==Data Input ' Weak point pressure(psi): Pio 1,591 psi Weak point pressure-Safety margin: Pmax 1,591 psi Pmax EMW 14.00 ppg Max anticipated formation pressure(psi): Pf 3,559 .81 Weak Pt to Zone of Interest distance(TVD ft): OH {TVD} 5,337' Weak Pt to Zone of Interest distance(MD ft): OH {MD) 11,753' Maximum influx height at the bit (ND ft): H {TVD) 1,742' Maximum influx height at the bit (MD ft): H {MD} 19,990' Calc.volume of(H)around BHA: V1bha 6.5 bbl Calc.volume of(H)around drill pipe: V1dp 1293.1 bbl Calc.volume that H equals @ initial shut in: VI 1299.7 bbl Calc.vol.that H equals @ weak point(MD ft): Vwp 369.0 bbl Calc.volume of Vwp @ initial shut in: V2 164.9 bbl Kick Tolerance: V2 164.9 bbl • • 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. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: G{AU, GLS " 1 O PTD: cu. —ill 7Development Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: l/i l/L. ?heir POOL: (.40/1/4,111k�. ' U&F4i', h 6,-/ 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 1 water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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