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Home My WebLink About218-0451. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8.Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 1:34 pm, Jul 29, 2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 218-045 50-103-20771-00-00 AA081798, AA081818, AA092346 MT6-05 None Greater Mooses Tooth Unit / Lookout Oil Pool 17391 7886 None None 17192 7892 10814 7963 Conductor 79' 20" 115 115 Surface 1978' 13.375" 2015 1977 Intermediate 8886' 9.725" 8921 7123 Tieback String 8621' 7" 8654 6935 SDL Liner 2533' 7" 11174 8006 Prod Liner 6158' 4.5" 17192 7892 11073 - 17192 7995 - 7892 4.5" L-80 see attached see attached see attached see attached see attached see attached 11073' - 17192' MD Please see attached summary 2420 5332 3214 1692 462 1606 2441 4881 1876 331 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ Kaylie Plunkett Digitally signed by Kaylie Plunkett Date: 2020.07.29 11:52:18 -08'00' RBDMS HEW 7/29/2020 DSR-7/29/2020VTL 8/11/20 SFD 7/30/2020 MT6-05 Scale Inhibition Treatment 6/27/20 – 6/28/20 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped from 0345 hrs on 6/27/20 to 0100 hrs on 6/28/20. LRS = Little Red Services CT = Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA – 295/1822/404 - RIH with CT to 16539’ CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.5 bpm while POOH to 11300’ CTMD - RBIH to 16780’ CTMD - Pumped 290 bbls 70/30 EG/Seawater and SCW3001 scale inhibitor through CT at 1.5 bpm while POOH to 11300’ CTMD. TBG/IA/OA – 1176/1412/0 - LRS pumped 2582 bbls Diesel/M209 over-flush at 5.0 bpm. TBG/IA/OA – 474/1176/0 Interval treated: 11073' - 17192' MD Tubing (size, grade, measured and true vertical depth) 4.5" L-80 10819’ MD 7964’ TVD Packers and SSSV (type, measured and true vertical depth) Packer: HRDE ZXP, 10814’ MD, 7963’ TVD SSSV: None Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:MT6-05 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: Install GLD 8/9/2018 MT6-05 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 36.5 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.42 Top (ftKB) 36.5 Set Depth (ftKB) 2,014.5 Set Depth (TVD) … 1,977.1 Wt/Len (l… 68.00 Grade L-80 Top Thread TXP Casing Description INTERMEDIATE #1 OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 34.6 Set Depth (ftKB) 8,920.8 Set Depth (TVD) … 7,123.1 Wt/Len (l… 40.00 Grade L-80 Top Thread TXP Casing Description TIEBACK STRING OD (in) 7 ID (in) 6.28 Top (ftKB) 32.6 Set Depth (ftKB) 8,653.8 Set Depth (TVD) … 6,934.5 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description SDL LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 8,640.7 Set Depth (ftKB) 11,173.7 Set Depth (TVD) … 8,005.7 Wt/Len (l… 32.00 Grade L-80 Top Thread Tenaris Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,640.7 6,925.2 45.04 PACKER SLZX Liner Hanger Packer 7.376 8,673.3 6,948.3 45.05 SEAL ASSY Latching bullet seals NO-GO (Seals 5.78') 6.180 8,676.1 6,950.2 45.05 Setting Sleeve HRD-E Liner Sleeve 7.735 8,685.0 6,956.5 45.05 QUICK CONNECT HP Liner Quick Connect,w/Bullet Seals 7" 32# Tenaris Blue 6.150 11,167.4 8,005.1 84.69 STABILIZER Reamer Shoe Stabilizer w/ Spline Profile, 7" 32# MYS110 Tenaris Blue 6.070 Casing Description PROD 1 LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 11,034.0 Set Depth (ftKB) 17,191.8 Set Depth (TVD) … 7,891.6 Wt/Len (l… 12.60 Grade L-80 Top Thread TXP Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 11,034.0 7,990.2 82.91 PACKER HRDE ZXP w/stepped Ext. 5.00" upper (10') 4.875" lower (10.35') H521 pin 3.875 11,065.5 7,994.1 82.90 HANGER 4-1/2" x 7" Flex Lock V TXP BxP 3.940 Tubing Strings Tubing Description TUBING PRODUCTION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 29.3 Set Depth (ft… 10,818.7 Set Depth (TVD) (… 7,963.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 29.3 29.3 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril 563 3.958 2,012.7 1,975.5 19.28 NIPPLE NIPPLE,LANDING,4 1/2",X,3.813", HYD563 3.813 10,084.9 7,799.7 68.54 GAUGE Schlumberger Solid Gauge Mandrel (SGM) w/ encapsulated I-wire, 4-1/2" 12.6# HYD563, PxP w/coupling 3.865 10,147.9 7,821.6 70.73 NIPPLE NIPPLE,LANDING,4 1/2", 3.75" DB, HYD563 3.750 10,803.3 7,961.5 82.68 NOGO LOCATOR Locator No-Go 5.76" OD 3.950 10,804.4 7,961.7 82.69 SEAL ASSY Seal Assembly Top of Seals 3.44' up from Mule shoe 3.950 Tubing Description PROD LEM ASSY String Ma… 4.6 ID (in) 3.95 Top (ftKB) 10,814.0 Set Depth (ft… 11,049.6 Set Depth (TVD) (… 7,992.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,814.0 7,962.9 82.73 PACKER HRDE ZXP w/ 16'sealbore ext. 5.00" ID 3.800 10,932.2 7,977.6 82.85 XO Top of LEM 3.700 10,935.4 7,978.0 82.85 SEAL BORE Upper Helix w/3.688" Seal Bore (10,932.81') 3.688 10,936.3 7,978.1 82.85 HOOK ASSY Latch 2.25' below Hook Hanger Internal Helix 3.688 10,938.3 7,978.4 82.85 LEM Lateral Entry Module "B" position 1 3.688 10,951.3 7,980.0 82.86 SEAL BORE Seal Bore 3.688" 3.688 11,002.8 7,986.4 82.89 NIPPLE Landing Nipple 3.313" "X" profile, HYD521 4.720" 3.300 11,042.6 7,991.3 82.91 SEAL ASSY Bullet Seal Assembly w/ 4.875" OD Seals 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 11,106. 2 7,999.2 82.91 WHIPSTOCK Whipstock TOW 11,106.2' / BOW 11,119.5 6/18/2018 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,659.4 3,384.5 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,736.0 8/9/2018 BK 2 6,490.7 5,408.0 Camco KBG-2 1 GAS LIFT GLV BK 0.188 1,777.0 8/9/2018 BK 3 10,017.8 7,774.1 Camco KBG-2 1 GAS LIFT OV BKO-3 0.250 8/8/2018 BKO-3 Notes: General & Safety End Date Annotation NOTE: MT6-05, 6/24/2020 10:05:30 AM Vertical schematic (actual) PROD 1 LINER; 11,034.0- 17,191.8 SDL LINER; 8,640.7-11,173.7 WHIPSTOCK; 11,106.2 SEAL ASSY; 11,042.6 NIPPLE; 11,002.7 SEAL BORE; 10,951.3 LEM; 10,938.3 PROD 2 LINER; 10,934.8- 15,039.7 HOOK ASSY; 10,936.3 SEAL BORE; 10,935.4 XO; 10,932.2 PACKER; 10,813.9 SEAL ASSY; 10,804.4 NOGO LOCATOR; 10,803.3 NIPPLE; 10,147.9 GAUGE; 10,084.9 GAS LIFT; 10,017.8 INTERMEDIATE #1; 34.6- 8,920.8 TIEBACK STRING; 32.6-8,653.8 GAS LIFT; 6,490.7 GAS LIFT; 3,659.4 SURFACE; 36.5-2,014.5 NIPPLE; 2,012.7 CONDUCTOR; 36.5-115.0 HANGER; 29.3 WNS PROD KB-Grd (ft) 36.47 Rig Release Date 7/14/2018 MT6-05 ... TD Act Btm (ftKB) 17,391.0 Well Attributes Field Name LOOKOUT Wellbore API/UWI 501032077100 Wellbore Status PROD Max Angle & MD Incl (°) 95.94 MD (ftKB) 15,931.32 WELLNAME WELLBOREMT6-05 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 2 1804 5 32 03 7 WELL LOG TRANSMITTAL 4906212257 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: MT6-05 Run Date: 1/11/2020 February 12, 2020 RECEI "! FEB 13 2020 AOGCL The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 MT6-05 Digital Data in LAS format, Digital Log Image file 50-103-20771-00 1 CD Rom MT6-05 is located in a federal oil and gas unit. Only with respect to the MT6-05 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(n(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halli�b/urton.com Date: / i Signed: L ConocoPhillips January 8, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Fourth 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 /14T6 --OS (218 -Oqs) Please find attached the fourth quarter 2019 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 2019. No annular disposal permits expired in the fourth quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, A-c� Lk G. L. Alvord Alaska Drilling Manager JAN 10 2020 A®GCC U) Q LL 0 w Q Z 0 Z> 0 U Z 0 NQ LL LU 0 Z 0 U U) Q Z Q J_ 0 R 1 G Q 0 a N Q Z Z LL 0 0 a. NW w i C � w d moo m _� 'E u Z Z Z Z Z O0, N O N 3 vLr)o O O d r - O O m o Q 0) w o t 0 N M O 0 � Z N M C m N O ) L j a❑ ¢ ¢ ¢ ¢ ¢ C o a m Z Z Z Z Z O a' o aEE 0 3 3 W d 0 w w a Z Qz Q) p L Z ❑ N p N L 0 c 4 p O `m _z Z .o y c Z Z Z Z Z O' N N a a Q m � c .� 2 -c w U co rn ai ai m o Q O 4 o a m !� d ❑ �; o a$ 0 0 0 0 o O �j m N E a w v �- ❑❑ a rn Z a 0 0 co O a O. m O a N N px N m 9 d LO V ❑ W ❑ 0 -a m O O O O ❑ (O (Op m N o N N U % N D! L � N Ea Elm ❑ a c O C3 to Z 0 F v d o m ❑ E U a r N > U C CL N 9O w O O O a N N 45 N❑ r o, _ c M O~ -c N z M > ti ❑ >. a U E o > a v n ❑ N V m 3-� > Y LL- a = c 3 O O O O O O c m 0 w' m a o Q a OL v a 7 m c ap ❑ L (0 a C l0 U ` _O "3 Q E�O. N O. Y O N OI 15 p a c m _ E❑ a c CY)O O Q o o m m c d �° w O O a'y/\ K 7E = U o N E N N N -cc a O m c❑ -a o p mri c w ¢ o. a p- t a x ami = a w w Q m O U ❑ v O d N O v 'C U a C N N L w N 0 co w U y d y y a v .c o ti w Y ❑ r c d u z m `� m m o N M v m E m E v. a m aai m a t 'c o m H K O Q U w m m m rn ry°- D o a W> Q om d p O O O N N = N ConocoPhillips October 8, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Third 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 mtr -os (2(8- 045) 4-4o l Please find attached the seeePid 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 third quarter of 2019, as well as total volumes disposed into annuli for which disposal authorization expired during the third quarter of 2019. 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 E fP IR o J U) N 0 02 o dCO)U Z 00 Q � LIJ �a U Z 7 O o Z �Q LL 00 Q J_ °0 CL gLLI Q so N 119 r v 0 11 F. lLl � O O m a o N x ¢ ¢ ¢ Q ¢ w w Z z Z Z O m N o N m LO o o o CO y c o o O ,G " 0 H 4 ° F- w o a O N m O C O N m o m d co z m h m m s •� - m z Emoa 43 m a - E z = - d ❑ ui a m z w L O o Q Q Q Q Q O N Z oc d E Zcl - z -o n c m 'c z z Z Z Z o m a C61 ai ai m kN ❑ �; o Ip m o. 5 N o O O O o O -� -0 El 1:1m Nj� U Z a O S 0 a�❑� o n o N Q e p V 0 g J d m N n N N x❑❑ -a O m LO O O O O ❑ ❑ W 3: c = r E = ° (O m O U 0 a m L m mo°❑ ❑ a N c = O U N rn C to Z C? y E d O F- d ❑ O o E m v M U y c K N ❑ ti a m y O O O O o. N L O R y0 C M N 0 ¢ h U M❑ W •C a m 3 N zo M v? N C (n L. Q "6 ❑ T O v v u> m E o G � o. ❑ s `m m U c 3 - m c 3 O O O O O O N a m O O m _) U � C N 41 m O. W� m❑ N 0) s o U = m E c 3 r € a .o m M E m. o Z. co W N m a ,� I� O O O O O �J m oO T a E w N a c m D_ X c = U m -o` w E o u N L N N O d m K a c o, W n Q N OoO O = O `-� E_ T'O N Y a L U U 'O m m ❑ N O a N O y C L .. u o .. o b O m r m y c a -2 ` L o U y s O m Z 'o_ n_ v -�a m E L di o -1 ] d L N m M N ❑ — so N 119 r v 0 11 F. ConocPhillips 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 APR 2 4 2019 AOGCC 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, Ali-ak 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: 218-045 ¢onocoPhillips:Alaska, Ina Development. �' Exploratory ❑ 7. Well Name: MT6-05 2. Address: '; - 4b. WelIxp� Weill Status: Oil Gas LJ WAG ❑ S. API Number: P. O Boz 100360 Anchorage, Alaska rr--I� GINJ El- WINJ I_I WDSPL ❑ 50-103-20771-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal [j] or Continuation ❑ or Final ❑ _ 318-395 _ 11/16/2018 Greater Mooses Tooth Unit 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): 25738.1 0 1216.1 26954.2 0 N/A N/A N/A 2019/1st 0 0 0 0 0 N/A N/A N/A 2019/2nd 0 0 0 0 0 N/A N/A N/A 2019/3rd 0 0 0 0 0 N/A N/A N/A 2019 / 4th 0 0 0 0 0 N/A N/A N/A Total Ending Volume 25738.1 0 1216.1 26954.2 o Report is due on the 20th (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure ❑ vs. Time Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true -and correct to the best of my knowledge. Signature: o"t Chip Alvord Date: 9`(45 12 t `i RBDMS APR Z 51019 Xe, v 0000 Printed Name: G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL RECEIVED JUL i 1 2019 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 218-04 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: MT6-05 2. Address: 4b. Well Status: Oil ❑� Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20771-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9, Field: Initial Disposal , or Continuation 9 or Final ❑ 318-395, 319-003 11/16/2018, 1/9/2019 Greater MooSeS Tooth Unit 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 Pmvious totals (bbls): 25738.1 0 1216.1 26954.2 0 N/A N/A N/A 2019/1st 0 0 0 0 0 N/A N/A N/A 2019/2nd 0 0 0 0 0 N/A N/A N/A 2019/3rd 0 0 0 0 0 N/A N/A N/A 2019/4th 0 0 0 0 0 N/A N/A N/A Total Ending 25738.1 0 1216.1 26954.2 0 Report is due on the 20th Volume of the month following the final month of the quarter. Ex: (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): I hereby certify thatforegoing is true and correct to the best of my knowledge. �the Signature: / I,^ Chip Date: "[�� (Z�(� RBDMSLIL 2 2 �l Y019 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 ConocoPhillips July 8, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Second 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 Please find attached the second 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 second quarter of 2019, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2019. 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 RECEIVED STATE OF ALASKA FEB 0 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 218-045 ConocoPhillips Alaska, Inc. Development ❑� Exploratory P P ry ❑ 7. Well Name: MT6-05 2. Address: 4b. Well Status: Oil ❑� Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ❑ WDSPL ❑ 50-103-20771-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sund approval date: �' pP 9. Field: Initial Disposal 21 or Continuation E] or Final ❑ 318-395 11/16/2018 Greater Mooses Tooth Unit 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 0 0 0 N/A N/A N/A 2018 / 1st 0 0 0 0 0 N/A N/A N/A 2018 / 2nd 0 0 402.5 402.5 1 5/22/2018 5/22/2018 LOT/Freeze Protect 2018/3rd 0 0 0 0 0 N/A N/A N/A 2018/4th 25738.1 0 813.6 26551.7 39 11/21/2018 12/29/2018 MT6-09, MT6-02 Total Ending Volume 25738.1 0 1216.1 26954.2 40 Report is due on the 20th (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure ❑ vs. Time Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): Freeze Protect I hereby certify that the�ftgreggoingg�is true and correct to the best of my knowledge. % Signature: �J(.c Chip Alvord Date: ((-jt Printed Name:! G. Alvord Title: Drilling Manager Phone Number: (907) 265-6120 ruin iu-4cc Kev. uzuu4 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate t�CL�@1"�S Oki IF "" r 6 219 ConocoPhiflips 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 6 ERIVD FEB 0 ? 2010 AOGCC 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: 218-045 ConocoPhillips Alaska, Inc. Development ❑' Exploratory ❑ 7. Well Name: MT6-05 2. Address: 4b. Well Status: Oil Gas ❑ WAG ❑ B. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50-103-20771-00-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9, Field: Initial Disposal ❑ or Continuation ❑' or Final ❑ 318-395 11/16/2018 Greater Mooses Tooth Unit 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 0 0 0 N/A N/A NIA 2018 / 1st 0 0 0 0 0 N/A N/A N/A 2016/2nd 0 0 402.5' 402.5 0 N/A N/A NIA 2018 / 3rd 0 0 0 0 0 N/A N/A N/A 2018/4th 25738.1 0 813.6 26551.7 0 N/A N/A N/A Total e"ding 25738.1 0 813.6 26954.2 o Report is due on the 20th Volume of the month followingthe final month of the Ex: (bbls): quarter. April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): * LOT, Freeze Protect 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. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-05 Permit to Drill Number: 218-045 Sundry Number: 319-003 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 Wv .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to annular disposal of drilling wastes in the above -referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, y`, Hollis S. French Chair t� DATED this T day of January, 2019. l % 9 �.Q19 RBOMS�.PN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ~ Tr=q pd"aVice® Val JAN 7 4 2019 aQGCC 1. Operator 3. Permit to Drill Name: 218-045 ConocoPhillips Alaska 4. API Number: 50-103-20771-00-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska MT6-05 6. Field: /firer—✓ opts 3 ..;: CclviNe�iver-kinit. Ln7 7. Publicly recorded wells 8. Stratigraphic description: /• .6 a) All wells within one-quarter mile: a) interval exposed to open annulus: MT6-03, MT6-08, MT6-04, MT6-09, MT6-06 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albion Torok Formation provide a lower bamer 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,200' MD and 1190' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: ts. Maximum anticipated pressure at shoe: 26,954 bbis as of 01101/2019 densities range from diesel to 1241gal 1861 14. Estimated volume to be disposed with this request: 15. Flulds to be disposed: 70,000 bbls. 181114 1/9/ �n Types of waste maybe drilling mud, drilling cuttings, reserve pit fluids, cement - U'lrOLg(. Opo 70000 contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 16. Estimated start ate. 20-DecA8 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Cement Bond Lo g (it required) ❑ FIT Records w1LOT Graph 71 Surf. Casing Cementing Data [a Other f] 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. /`:K Signature: ,& (.L�'l Title: �Ilrf�tin� IVI Printed Phone Number (3 Name: Chip Alvord 265.6120 Date: I I2 , I 1 Commission Use Only Conditions of approval: LOT review and approval: .pt Ih `S✓ Subsequent form r 10— +.0'7 3 Approval I` l l U V required: .�� number. APPROVED BY Approved by: q COMMISSIONER THE COMMISSION Date: r'� II 1 wf 1 z0f9 - Form 10-403AD Rev. 512004 0 Rj T O S ON REVERSE SubmB In Uupllcate .T r iw 1I ql Z0�9 v17-6/`l/jj A LRBDMS` 1AN 0 3� %./�� g �% ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 3rd, 2018 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Arilline Waste on well MT6 05 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for MT6-05 (sundry permit # 318- 395) be re -permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on MT6, it is requested that the volume limit described in 20 -ACC 25.080 d. 1. be increased from 35,000 bbl. to 70,000 bbl. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized, and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. MT6-05 is currently being used for annular disposal and has injected a total volume of 26,954 bbls. Increasing the allowable disposal volume for MT6-05 will allow for time to drill more wells and potentially permit other candidates for annular disposal. For further details, please reference the annular disposal permit for MT6-05, approved on November 16, 2018. Attached is an updated table showing all the wells drilled within quarter mile of the surface shoe on MT6-05. Additional information regarding wells within '/a mile radius that have not previously been submitted to the AOGCC are included. Also attached is the updated annular disposal transmittal form. If you have any questions or require further information, please contact Nina Anderson at 229-4008 or Chip Alvord can also be reached by calling 265-6120. Sincerely, Nina Anderson Drilling Engineer cc: MT6-05 Well File Chip Alvord ATO -1570 Annulus Disposal Transmittal Form - Well MT6-05 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: M76-05 2 The depth to the base of freshwater aquifers and permafrost, There are no freshwaer aquifers in the affected area of the if present. Lookout Oil Pool. Estimated base of Permafrost = 1190' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The shales of the Upper Seabee formation (Above C-30) annulus and other information sufficient to support a provides the upper barrier and the shales of the Lower Seabee commission finding that the waste will be confined and will Formation (below C-30) provide a lower barrier. Calculated not come to the surface or contaminate freshwater. water salinities of the Cretaceous and older stratigraphy sections range from 13,000 to 31,000 ppm. There are no freshwater aquifers in the affected area of the LOP (Lookout Oil Pool)(Ref. AOGCC Area Injection Order No. 40, Pg. 7, May 29, 2018) 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 l mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 70,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CDI&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 1861 psi. Including a 100 psi buffer, calculations showing how this value was determined. the Maximum anticipated pressure would be 1761 psi. See attached calculation 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. I Identification of the hydrocarbon zones, if any above the The top of cement is 7921' 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 lobe disposed of was or MT6-06, MT6-04, MT6-09, MT6-07, MT6-02, MT6-01 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. SURFACE CASING SHOE SEPARATION FROM MT6-05 planned MT6-05 planned x v Surface Casino Shoe ASP 4 Coordinates NAD 27: 316810.21 5945736.16 Wells Ann. Details @ Disp. Source AOGCC Permit # Permit Date wells Ann. Vol. - Start Date Distance 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) Comments MT6.03 Y 316 317125.92 5945754.12 15.1 2052 14.5 MT6-OS Y 318-395 11/16/2018 MT13-09, MT6-02 16,954.00 11/21/2018 0 316810.21 5945736.16 18.1 1977 16,1 Aproved Sundry MT6-08 Y 109 316910.89 5945693.30 18.0 1984 Not an annular injection can i ate MT6-06 N 171 316859.42 5945899.85 18.0 2003 15.0 MT6474 N 326 317028.00 5945493.08 18.5 2029 15.90 MT6-09 N 1 3291 316480.74 5945732.69 16.5 2030 13.40 MT6-02wp08 349 316903.65 5945400.13 MT6-01wp02 344 317148.51 5945672.15 410 317219.47 5945756.37 ' Lateral distance in feet, between surface casing shoes, in the X -Y plane Note that this sheet is not the definitive record for annular disposal volumes Last Update 1/3/2019 All walls highlighed in blue are within a quater mile Additional information regarding the following wells that are within %4 mile radius that have not previously been submitted to the AOGCC are included: MT6-06 [NWOSIZI MT6-09 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-09 Rig: Doyon 19 1 Date: 1 11/23/2018 Drilling Supervisor: IR. Bjorhus /A. Dorr Pump used: #1 Mud Pump W Type of Test: casing Shoe Test LOT/FIT 1W Pumping down annulus and DP. V Hole Size: 12-1/4" Casing Shoe Depth Hole Depth -Volume Input strokes 'W Volume/Stroke 0.1000 8bls/Strk ' Pump Rate: 0.5018bl/min IV asmg Test I Pressure Integrity Test Pumping Shut-in Pumping Shut-in RKB-CH 36.7 Ft I 2146.0 Ft-MD 030.0 Ft-TVD-174.0 Ft-MD 054.0 t-TVD -- - -- Casing Size and Description: 13-3/8" 68#/Ft L-80 BTC -• tr s psi Min psi trks psi Min psi 0 0 0 2610 1 50 0.00 540 Casing Test Pressure Integrity I est 2 80 1 2610 -2-90 0.25 500 Mud Weight: 10.0 ppg Mud 10 min Gel: 21.0 Lb/100 Ft2 Test Pressure: 2500.0 psi Rotating Weight: Lbs Blocks/fop Drive Weight 60000.0 Lbs Estimates for Test: 2.8 bbls Mud Weight: 10.5 ppg Mud 10 min Gel: 17.0 Lb/100 Ft2 Lbs Blocks/Top Drive weight: 60Lbs Rotating Weight:M18.0 Desired PIT EMW: ppg Estimates for Test: 792 psi 0.9 bbls 4 200 -6-350 2 2610 -3-150 .50 450 3 2610 4 220 1.00 400 8 550 4 2610 5 300 1.50 375 10 5 2610 6 370 2. 375 12 900P20 2610 ---7--4-50 2.50 375 14 1 D50 2610 8 520 3.00 350 16 1175 2610 9 540 3.50 350 EMW = Leak-off Pressure + u Weight = 540 + 10.5 0.052 x TVD 0.052 x 2030 EMW at 2146 Ft-MD Ft-TVD) _ 15t�pg P1T 15 Second18 Shut-in Pressure, psi 1300 2610 10 540 4.00 350 20 1400 2610 11 540 4.50 350 500 22 1550 2600 12 540 5.00 350 soon 2500 2000 LU o: N 1500 to LU o loon 50 0 4 Lost 20 psi during test, Id-99'2 #S 24 1700 2595 5.50 350 26 1750 2595 -30-2590 6.00 350 _ 28 1850 6.50 340 s - 30 2000 7.00 340 _ 32 2150 7.50 340 01P- 34 2300 8.00 340 3 2450 8.50 340 38 2610 9.00 340 9.50 340 10.00 340 0 1 2 3 Barrels - CASING TEST BLEAK-OFF TEST 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Part o ume o ume Bled Back o ume Pum ed volume Bled Bakll� s s Comments ested casing with 10.0 DrilPlex mud 13:30 Hrs 11/23/18 Performed LU T to 15.6 ppg with 10.5 LSND mud 21:00 Hrs 11/23/18 MT6-09 Surface Casing - Test-LOT.xlsx Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-09 Rig: Doyon 19 1 Date: 11/30/2018 Volume Input Drilling Supervisor: K. Harding/A. DoIT _. Pump used: Other -See Comments (Barrels W Bbls/Strk Pump Rate: 0.30 Bbl/min Integrity est Type of Test: Annulus Leak Off Test for Disposal Adequacy ♦ _ Pumping down annulus. 111111"I asmg Test I Pressure Hole Size: 12-1/4" • Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 36.7 Ft 1 2146.D Ft -MD 2030.0 Ft -TVD 9395.0 Ft-MD6683.0 Ft -TVD Casing Size and Description: 13-3/8" 68#/Ft L-80 BTC q Bbls psi Min psi Bbis psi Min psi 0 0 0 0.00 260 Changes for Annular Adequacy Test Pressure IntegrityTest 1 0.5 40 0.25 250 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. Mud Weight: 10.6 Inner casing OD: 9.625 Desired PIT EMW: 15.6 Estimates for Test: 528 ppg In. ppg psi 1 bbls 2 1 40 0.50 240 3 1.5 50 1.00 230 4 2 60 1.50 220 5 2.5 85 2.00 22( 6 3 110 2.50 210 7 3.5 150 3.00 210 8 4 190 3.50 210 EMVV= Leak -off ressure + Mud Weight= 297 0.052 x TVD 0.052 x 2030 + 10.6 EMW at 2146 Ft -MD (2030 Ft -ND) = 13.4 PIT 15 Second Shut-in Pressure, psi 9 4.5 230 4.00 200 10 5 280 4.50 200 250 15 5.5 305 5.00 200 Sao W y W a 0 o s Shut O 201 6 305 5.50 200 25 1 6.5 3001 6.00 200 30 1 7 2901 6.50 190 7.5 290 7.00 190 8 290 7.50 190 8.5 285 8.00 190 9 290 8.50 190 9.00 190 9.50 190 10.00 180 0 2 4 �CASING s Barrels TEST e BLEAK m 12 -OFF TEST 14 10 -In PIT Point is time, 20 Minutes 25 30 Volume PUm ed Volume Bled Back Volume Pum ed Volume Bled Back S S s S Comments: Pumped 9 bbls 10.6 ppg _SND for LOT, 300 bbls H2O water flush 85 bbls diesel freeze protect. 13-3/8" Shoe LOT = 15.6 ppg on 11/23/18 Used Ball Mill injection pump #1 oullwidly Time Log & Summary Report [AOGCC] MT6-09 Well Name: MT6-09 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/19/2018 Rig Release: 12/22/2018 Time Log Dur Stan Depth End Depth T..P Stars Time End Time (hr) (Pots) (RKB) Mese DD Code Ac dy Code -T-X Operation 11/20/2018 11/21/2018 1.00 2,154.0 2,061.0 SURFAC CASING CIRC P Pump sweep & circulate dean w/860 gpm, 2380 23:00 00:00 psi, 30 rpm, 2.5 k trq. Rack back 1 stand f2,154' to 2,061' 11/21/2018 11/21/2018 2.00 2,061.0 1,778.0 SURFAC CASING CIRC P Pump sweeps & circulate dean for 5 B/U total 00:60 02:00 w/860 gpm, 2450 psi, 40 rpm, 2.5 k trq. Rack back 1 stand each f/2,061' to 1,778' 11212018 11/21/2018 0.25 1,778.0 1,778.0 SURFAC CASING OWFF P F/C (static) B/D top drive 02:00 02:15 11121/2018 11/21/2018 1.00 1,778.0 1,158.0 SURFAC CASING TRIP P POOH 1/1,778' to 1, 158'. Not able to POOH thru 02:15 03:15 1 base of permafrost Not able to slack off. 11/21/2018 11/21/2018 0.25 1,158.0 1,308.0 SURFAC CASING REAM T Reaminholefrom 1,158'tc1,212'w/400gpm, 03:15 03:30 30 rpm. RIH on elevators 1/1,212'to 1,308' 11/21/2018 11/21/2018 0.50 1,308.0 1,212.0 SURFAC CASING BKRM T BROOH f/1,308' to 1,212'W700 gpm, 1600 psi, 03:30 04:00 40 rpm, 1.5 k trq. Hole unloaded significant amount of cuttings. 11121/2018 11/21/2018 0.25 1,212.0 1,117.0 SURFAC CASING TRIP T POOH f/1,212'to 1,117'. Drop Gyro tool. B/D top 04:00 04:15 drive. 1121/2018 11/21/2018 2.25 1,117.0 90.0 SURFAC CASING TRIP P POOH f/1, 117'to 90'. Rack back HWDP, Jam & 0415 0630 1 1 1 NMFC. Retrieve Gyro tool. 11/21/2018 11/21/2018 0.50 90.0 90.0 SURFAC CASING CIRC P Pump nut pulg sweep to aid in cleaning up BHA 06.30 107ZO w/550 gpm, 780 psi, 40 rpm, 1 k trq 11121/2018 1121/2018 1.75 90.0 0.0 SURFAC CASING SHAH P UD BHA as per Baker reps 07:00 08:45 11/21/2018 11212018 1.00 0.0 0.0 SURFAC CASING BHAH P Clean & dear floor of BHA tools & equipment. 0845 09:45 11/21/2018 11/21/2018 2.75 0.0 0.0 SURFAC CASING RURD P R/U to run casing. RN Volant, bale extensions, 09:45 12.30 slips & elevators. 1121/2018 11/21/2018 2.00 0.0 161.0 SURFAC CASING PUTS P PJSM on casing. M/U shoe track & check floats 12:30 14:30 1 1 1 (good). 11212018 11/21/2018 3.50 161.0 161.0 SURFAC CASING PUTB T Had to swap jts 5,6, & 7 & collar of it #4 due to 14:30 18:00 1 BTC casing cross threading 11212018 11/21/2018 4.50 161.0 1261.0 SURFAC CASING PUTS P RIH 13-3/8" 68# L-80 BTC/TXP casing f/161'to 1800 22:30 1,261' Washed down @ 3 bpm 0,100'to 1,261' 11/21/2018 1121/2018 0.50 1,261.0 1,261.0 SURFAC CASING CIRC P Cim B/U & Gond mud. Stage flow rate up to 5 22:30 2300 bpm, 130 psi. Reciprocate pipe. 11/21/2018 11/22/2018 1.00 1,261.0 1,540.0 SURFAC CASING PUTB P Cont. RIH 13-3/8" 1 L-80 TXP casing f11,261' 23:00 00.00 to 1,540'. S/0 wt 105 k 1122/2018 1122/2018 2.00 1,540.0 2,067.0 SURFAC CASING PUTS P Cont. RIH 13-3/8"68#L-80 UP casing f/1,540' 00:00 02:00 1 Ito 2,067' S/0 wt 130 k 1122/2018 1122/2018 1.00 2,067.0 2,146.0 SURFAC CASING HOSO P M/U hanger & landing it. Wash down w/3 bpm @ 0200 03:00 200 psi & land on hanger @ 2,146'. PAJ wt 157 k, S/0 wt 132 k. 11/222018 1122/2018 1.50 2,146.0 2,146.0 SURFAC CEMENT CIRC P Circ & oond mud for cement job. Stage flow rate 03:00 04:30 up to 8 bpm @ 220 psi. Reciprocate pipe 10' 11/222018 11222018 0.50 2,146.0 2,146.0 SURFAC CEMENT RURD P B/D top drive. R/U cement lines. 04:30 0500 11/ 18 11/222018 2.50 2,146.0 2,1469 SURFAC CEMENT CIRC P Circ& cond mud for cement job w/8 born @400 05:00 07:30 psi. Reciprocate pipe 10'. SIMOPS - PJSM on cemenfng. Page 2/20 Report Printed: 113/2019 AL Time Log & Summary Report [AOGCC] MT6-09 Well Name: MT6-09 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/19/2018 Rig Release :12122/2018 Time Log Dv Start Depth End Depth T.. P Start hme End Time @r) (WB) (flK6) Phase Op Cade Fl ity Cade -T-X operetlOn 11/22/2018 11/22/2018 11 15 3.75 21146.0 2,146.0 SURFAC CEMENT CMNT P Dowell pump 3 bbis H2O & PT to 3500 psi 0730 (good). Dowell pump 100.2 bbis 10.3 ppg Mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 330 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 68.3 We 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace with 289 bbis / 2,893 stks 10 ppg DrillPlex with 8 bpm / 850 psi. Reduce pumps to 3 bpm / 550 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. F/C good. CIP @ 11:15 Hrs, Calculate 154 bible good cement to surface. Full returns during cement job. 11/22!201811:15 11/22/2018 2.00 0.0 0.0 SURFAC CEMENT RURD P Flush riser w/black water. R/D Volant & casing 13:15 running tools & equipment. LID landing jt 11/22/2018 11122/2018 1.50 0.0 0.0 SURFAC CEMENT RURD P R/D surface riser asst' N/D speed lock head 13:15 14:45 adaptor SIMOPS -clean pits. 11/22/2018 11/22/2018 0.75 0.0 0.0 SURFAC WHDBOP NUND P N/U well head & test to 1000 psi for 10 min 1445 15.30 (good). SIMOPS - clean pits. 11/22/2018 11/22/2018 2.25 0.0 0.0 SURFAC WHDBOP NUND P NIU BOPE & NN chokelkill lines. $[MOPS - 15:30 17:45 dean pits. 11/22/2018 11/2212018 2.75 0.0 0.0 SURFAC WHDBOP MPDA P N/U RCD damps & orbit valve. N/U flow line & 17:45 20:30 flow box. Install annulus valves. Obtain RKB's. Install trip nipple. Install KatchKan. 1122/2018 11/22/2018 1.50 0.0 0.0 SURFAC WHDBOP MPDA P R/U test equipment. Test MPD equipment 20:30 2200 250/1500 psi. R/D testing equipment & in stall trip nipple. SIMOPS - M/U choke & flare lines. 11222018 11/22/2018 0.50 0.0 0.0 SURFAC WHDBOP RURD P Install test it & R/U to test BOPE 22:00 2230 1122/2018 11/23/2018 1,50 0.0 0.0 SURFAC WHDBOP BOPE P Test BOPE w/5" test it. Annular 250 psi 5 min / 22:30 0000 2500 psi 10 min. Test 3.12" X 6 VBR's, choke valves 1 - 14, Man IBOP, HCR kill & dart valve 250 psi 5 min / 3500 psi 10 min. 11/23/2018 1123/2018 4.50 0.0 0.0 SURFAC WHDBOP BOPE P Test ROPE w/5 test joint. Annular 250 psi for 00.00 04:30 min 12500 psi for 10 min, Remaining test 250 psi for 5 min / 3500 psi for 10 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 5" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3,050 psi, final 1,490 psi, 1st 200 psi recharge = 31 sec's, full recharge = 161 seconds. Nitrogen Bottles x4 = 2,050 psi. Gas alarms and PVT alarms tested. Draw down on chokes 1:11100 psi. AOGCC Brian Bixby & BLM Mutasim Elganzoory waived witness. 11/23/2018 11232018 1.00 0.0 0.0 SURFAC WHDBOP RURD P R/D testing equipment. B/D lines. Pull test plug & 04:30 05:30 set 12.375" ID wear ring. 11232018 11232018 3.50 0.0 157.0 SURFAC CEMENT BHAH P PJSM. M/U 12-1/4" BHA #2 as per Baker reps 05:30 09:00 11/23/2018 1123/201811:30 2.50 157.0 1,933.0 SURFAC CEMENT TRIP P RIH 1/15Tto 1,933' 0900 11/23/201811:30 1123/2018 0.50 1,933.0 1,933.0 SURFAC CEMENT DHEO P Shallow hole test MWD tools. 12:00 11/23/2018 11/232018 1.50 1,933.0 1,933.0 SURFAC CEMENT SLPC P Slip & cut drill line. Service rig. 12:00 13:30 11/23/2018 111232018 1.50 1,933.0 1,933.0 SURFAC CEMENT PRTS P R/U testing equip. Test casing to 2500 psi & 13:30 15:00 chart for 30 min. R/d testing equip. 1123/2018 11232018 5.00 1,933.0 2,154.0 SURFAC CEMENT DRLG P Drill out cement & shoe track to 2,154'w/45 - 15:00 20:00 600 gpm, 500 - 800 psi, 40 - 80 rpm, 2 - 5 k trq. Displace to new 10.5 ppg LSND on the fly. 1123/2018 112312018 0.25 2,154.0 2,174.0 SURFAC CEMENT DDRL P Drill 20'new formation f/2,154' to 2,174' MD/ 20:00 20:15 2,054' TVD w/600 gpm, 830 psi, 80 rpm„ 5 - 6 k trq. Page 3/20 Report Printed: 1/3/2019 Time Log & Summary Report [AOGCC] MT6-09 Well Name: MT6-09 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11 /1 912 01 8 Rig Release : 12/22/2018 Time Log our Sten Depth End Depth Tune P Stan Time End Time (hr) (ftKB) (111(8) Phos@ op Code Advity Code -T-X operate. 11/27/2018 11/27/2018 2.25 9;646.0 7,790.0 INTRMI CASING SMPD P StriP00H f/9,846'to 7,790' as per MPD 00:00 02:15 schedule. Various fight spots w/ 30 k over pull. Not able to make forward progress past 7,790'. Work thm several times with minimal success. Decision made to back ream. 11/27/2018 11/27/2018 0.50 7,790.0 8,080.0 INTRMI CASING TRIP P RIH U7,7901 to 8,080'. PJSM on installing trip 0215 02:45 nipple. 11272018 1112712018 0.50 7,790.0 8,080.0 INTRMI CASING MPDA P F/C (static). Pull RCD & install trip nipple. 02:45 03:15 11/27/2018 112712018 8.75 8,080.0 5,238.0 INTRMI CASING BKRM P BROOH f/8,080'to5,238'w/925gpm, 2820- 03.15 12:00 2500 psi, 120 rpm, 11.5 -9 k trq. Hole un -loading significant amount of cuttings & caving's periodically. 11127/2018 11/28/2018 12.0 5,238.0 1,275.0 INTRMI CASING BKRM P BROOH f/5,238- to 1,275'w/925 gpm, 2500 - 12:00 0000 0 1800 psi, 120 - 140 rpm, 10 - 4 k trq. Hole attempting to pack off through out with significant amount of cuttingslcavings on shakers. The hole un -loaded softball & football size clay balls & caving's at 2600'. Performed 275 bbl dilution @J 4,000'. Pumped sweeps to aid in hole cleaning. 11/28/2018 11282018 1.50 1,275.0 61.6.0 INTRMI CASING BKRM P BROOH f/1,275'to 616'w/920 gpm, 1620 psi, 0000 01:30 140 rpm, 1.5 k trq. Hole continued un -loading softball size clay balls & caving's. 11/28/2018 11.282018 2.25 616.0 585.0 INTRMI CASING CIRC P Pump high vis nut plug weighted sweep & circ & 01:30 03:45 cond to 10.5 ppg in/out w/920 gpm, 1570 psi, 30 rpm. Reciprocate pipe to 585' 11281201.8 11/28/2018 0.25 585.0 585.0 INTRMI CASING OWFF P F/C (static) SIMOPS - BID top drive & PJSM on 03:45 0400 BHA 11/28/2018 1128/2018 0.75 585.0 157.0 INTRMI CASING TRIP P POOH f/585 to 157'. Rack back HWDP & Jars 0400 04:45 11/28/2018 11/28/2018 1.25 157.0 0.0 INTRMI CASING BHAH P UD BHA as per Baker reps f/157' 04:45 06:00 11/28/2018 11282018 1.25 0.0 0.0 INTRMI CASING W W WH P Pull wear ring. M/U Johnny Wacker & flush stack 06:00 07:15 2X 11282018 11282018 2.25 0.0 0.0 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 9 518". Set 07:15 09:30 test plug & R/U to test BOPE. SIMOPS - Clean & clear floor. Mobilize casing running tools to rig floor. 1128/2018 11/28/2018 11:00 1.50 0.0 0.0 INTRMI CASING ROPE P Test annular preventer to 250 for 5 min 12500 09:30 psi for 10 min. Test upper pipe rams to 250 for 5 min 113500 psi for 10 min. 11!28/2018 11:00 11/28/2018 11:30 0.50 0.0 0.0 INTRMI CASING BODE P RID testing equipment. Set 13.125" wear ring. 11/28/2018 11:30 11282018 2.00 0.0 0.0 INTRMI CASING RURD P Dummy run hanger. R/U to run casing. RAJ 13:30 Volant, spider's & elevators. 1128/2018 1129/2018 10.5 0.0 6,030.0 INTRMI CASING PUTB P PJSM on running rasing. M/U 9-5/8" 40# TN -80 13:30 0000 0 TXP shoe track to 160'. Check floats (good). RIH 9-518" 40# TN -80 TXP casing f/160' to 6,030' 11292018 11/292018 6.50 6,030.0 9,043.0 INTRMI CASING PUTB P RIH 9-518" 40# TN -80 TXP casing f/6,030'to 00:00 0630 9,043'. S/0 wt starting to diminish w25 k drag. P/U wt 335 k I S/0 wt 205 k 11/29/2018 11/29/2018 1.25 9,043.0 9,076.0 INTRMI CASING CIRC P Break circ & stage pumps up to 4.5 bpm 1620 06:30 07:45 1 1 psi. Circ & cond mud f/ 9,043' to 9,076' 1129/2018 11/292018 5.75 9,076.0 10,358.0 INTRMI CASING PUTB P Cont. RIH 9-5/8" 40# TN -80 TXP casing while 07:45 13:30 washing down w/3 bpm 1600 psi f/9,076' to 10,358' 1129/2018 112912018 0.50 10,358.0 10,395.0 INTRMI CASING HOBO P M/U hanger & landing jt. Wash down w/3 bpm I 13:30 14:00 600 psi & land on hanger Q 10,395' (SIO wt 200 k, not able to work pipe up) 11292018 11/292018 3.25 10,395.0 10,395.0 INTRMI CEMENT CIRC P Break circ & stage pumps up to 8 bpm / 580 psi. 14:00 17:15 Circ & cond mud for cement job. 1129/2018 11/2912018 0.50 10,395.0 10,395.0 INTRMI CEMENT RURD P Shut down, F/C static. Blow down top drive, Rig 17:15 17:45 up cement hose and 1502 equipment to cement line. Break circ w/8 bpm 1840 psi. Page 5120 Report Printed: 1/3/2019 Time Log & Summary Report [AOGCC] MT6-09 Well Name: MT6-09 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11119/2018 Rig Release; 12/22/2018 Time Log Dur Start Depth End Depth Tepee Start Time End Time (hr) pl K6) (ftKB) Phase op code A tNfty Code -T-x Operation 11/29/2018 11/29/2018 425 10,395.0 10,395.0 INTRMI CEMENT CMNT P Dowell pump 1.2 bbls H2O & PT to 4000 psi 17:45 22:00 (good). Dowell pump 60 bbis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 36.2 bible 12.2 ppg 2.3 ft3lsx yield Class G lead cement and 42.4 We 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbls H2O. Rig displace with 762 bbls (7,640 stks @ 95%) 10.5 ppg LSND with 8 bpm / 500 - 850 psi. Reduce pumps to 3 bpm / 570 psi. last 10 bible. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. FIC good. CIP @ 21:50 Hrs. Full returns during cement job. 1/292018 11/29/2018 1.25 0.0 0.0 INTRMI CEMENT OWFF P Monitor well. Static. SIMOPS -R/D Volant&L/D 22:00 23:15 I landing jt. 11/292018 11/302018 0.75 0.0 0.0 INTRMI CEMENT RURD P Drain stack & R/U to flush stack 2315 0000 11/30/2018 11/30/2018 1.00 0.0 0.0 INTRMI CEMENT WWWH P MIU Johnny Wacker &flush stack. 00:00 01.00 11/30/2018 11/30/2018 0.75 0.0 0.0 INTRMI CEMENT W WSP P FMC Pull thin wall wear ring. Set 9-5/8" packoff 01:00 01:45 and test to 5000 psi for 10 minutes, CPAI witnessed (good) 11/30/2018 11/30/2018 4.25 0.0 0.0 INTRMI CEMENT NUND P PJSM on N/D BOPE. De -energize Koomy. 01:45 06:00 Remove mouse hole. Break choke connection. Pull trip nipple & N/D flow line, flow box, hole fill & bleeder lines. Install 7" spool & test void to 5000 psi (good). NIU BOPE on 7" spool. 11/30/2018 11/3012018 2.50 0.0 0.0 INTRMI CEMENT MPDA P RA1 MPD package. M/U flow box & NIU hole fill 06:00 08:30 bleeder lines. M/U choke lines. Install trip nipple. 11/30/2018 11/30/2018 3.75 0.0 0.0 INTRMI WHDBOP RURD P C/O upper rams to 4-1/2" X 7" VBR's. Obtain 0830 1215 RKB's. Grease choke manifold. Install mouse hole. Set test plug. Fill stack w/H20. Purge air from system. R/U to test BOPE. 11/30/2018 11/30/2018 7.00 0.0 0.0 INTRMI WHDBOP BOPE P Test BOPE w/4", 5", & 7" test joints. Annular 250 12:15 19:15 psi for 5 min / 2500 psi for 10 min, Remaining test 250 psi for 5 min / 3500 psi far 10 min. 4" Demco, Choke valves 1 -14; IBOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, Lower 3- 12" X 6" VBR's & blind rams, 5" Dad/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3,000 psi, final 1,450 psi, 1st 200 psi recharge = 37 sec's, full recharge = 160 seconds. Nitrogen Bottles x4 = 2,100 psi. Gas alarms and PVT alarms tested. Draw down on chokes V1100 psi. AOGCC Guy Cook waived witness of test. 111302018 11/30/2018 2.25 0.0 0.0 INTRMI WHDBOP RURD P R/D testing equipment. BID lines. Install 8.8125" 19.15 21:30 wear ring. SIMOPS- RIU lines on BPA. Stage BHA tools & equipment. 11/30/2018 11/30/2018 1.00 0.0 0.0 INTRMI CEMENT SFTY T Clean up centrifugal room & pump room from 21:30 22.30 spill. ACS inspect mat boards. 11/302018 11/30/2018 0.50 0.0 399.0 INTRMI CEMENT SHAH P M/U 8-3/4" clean out/kick off BHA as per Baker 22:30 23:00 reps. 11/302018 12/12018 00:00 1.00 399.0 1,814.0 INTRMI CEMENT TRIP P RIH f/399' to 1,814- 2300 1211201800:00 1211/201805:00 5.001 1,814.0 10,000.0 INTRMI CEMENT TRIP P RIH f/1,814' to 10,000- 121112018 05:00 12/1/2018 05:30 0.50 10,000.0 10,090.0 INTRMI CEMENT CIRC P Circ & cond w/350 gpm, 890 psi f/10,000'to 10,090- 1211/2018 05:30 12/1/2018 07:30 2.00 10,090.0 10,090.0 INTRMI CEMENT PRTS P B/D top drive. RIU to test casing to 3500 psi & chart for 30 min (good). RID testing equipment. 12/12018 07:30 1211/2018 08:30 1.00 10,090.0 10,090.0 INTRMI CEMENT SLPC P Slip & cut drill line. 12/12018 08:30 12/1/2018 09:30 1.00 10,090.0 10,312.0 INTRMI CEMENT COCF P W&R f/10,090' & tag TOC @ 10,312' w/400 gpm, 1190 psi. Page 6/20 Report Printed: 1/3/2019 - Cement Detail Report MT6-09 String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/191201800:00 Cement Details Description Cementing start Date Cementing End Date Wellbore Name Surface Casing Cement 11/22/2018 07:30 11/22/2018 1115 MT6-09 Comment Dowell pump 3 bets H2O & PT to 3500 psi (goad). Dowell pump 100.2 bbis 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 330 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 68.3 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 289 bbis / 2,893 stks 10 ppg Dnl[Plex with 8 bpm 1850 psi. Reduce pumps to 3 bpm 1550 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. FIC good. CIP @ 11:15 Hm Calculate 154 bbls good cement to surface. Full returns during cement job. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Bun Plug? Surface Casing Cement Cement Surface Casing 36.6 2,146.0 Yes 154.0 Yes Yes O Pump int (bbl/m-0 Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (it) Rotated? Pipe RPM (rpm) 8 3 6 550.0 1,100.1 No No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 3 bbis H2O & PT to 3500 psi (good). Dowell pump 100.2 bbis 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 330 bbls 11.0 ppg 1.95113/sx yield LiteCRETE lead cement and 68.3 bbis 15.8 ppg 1.16 ft31sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace with 289 bbls / 2,893 stks 10 ppg DrillPlex with 8 bpm 1850 psi. Reduce pumps to 3 bpm / 550 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. FIC good. CIP @ 11:15 Hrs. Calculate 154 bbis good Camarillo surface. Full returns during cemem job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ft(B) '.Est BIM (ftKB) Amount (sacks) Class Volume Pumped (bbl) Surface Cement 1 36.6 1,646.0 950 B 330.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density gb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.95 7. 1 15.20 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est etm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,646.0 2,146.0 331 C 68.3 Yield (fetsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.10 15.80 5.20 Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 1/3/2019 AL N. ; Cement Detail Report MT6-09 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 11/1912018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/29/2018 1830 11/29/2018 21.50 MT6-09 Comment Dowell pump 1.2 bbis H2O & PT to 4000 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 36.2 bbls 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 42.4 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbis H2O. Rig displace with 762 bbls (7,640 stks @ 95%) 10.5 ppg LSND with 8 bpm 1500 - 850 psi. Reduce pumps to 3 bpm 1570 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. FIC good. CIP @ 21 50 Hrs. Full returns during cement job. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Son Plug? Intermediate Casing 1000' of cement above 9,395.0 10,395.7 Yes Yes Yes I Cement shoe Q Pump lnh (bbgm... IQ Pump Final (bbl/... IQ Pump Avg (boll... P Pump Flnal (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? I Pipe RPM (rpm) 8 13 6 570.0 1,100.0 1 No I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 1.2 bbls H2O & PT to 4000 psi (good). Dowell pump 60 Dols 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 36.2 bbis 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 42.4 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbls H2O. Rig displace with 762 bbls (7,640 stks @ 95%) 10.5 ppg LSND with 8 bpm 1500 - 850 psi. Reduce pumps to 3 bpm / 570 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1100 psi for 5 min. Check floats. F/C good. CIP @ 21:50 Him. Full returns during cement job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est she (ftKB) Amount (sacks)Class Volume Pumped (bbl) Lead Cement 9,395.0 9,895.0 89 G 36.2 Yield (Wlsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 2.30 13.16 12.20 6.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluitl Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (ball Tail Cement 9,895.0 10,395.7 204 G 42.4 Yield (Wisack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.07 15.80 4.50 Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 1/3/2019 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-06 Rig: Doyon 19 Date: 9115/2018 Drilling Supervisor: A. Dorr / D. Guzman Pump used: a2 Mud Pump W Volume Input Volume/Stroke Pump Rate: strokes ♦ 0.1000 Bbls/Strk W 0.50 Bbi/min Type of Test: Casing Shoe Test LOT/FIT 'W Pumping down annulus and DP. 1W Hole Size: 12-1/4" • I Casing Shoe Depth I I Hole Depth asmg Test I Pressure Integrity Test Pumping Shut-in Pumping Shut-in RKB-CHF:j 35.91 Ft I 2118.0 t -MD 2003 0 Ft -TVD 2149.0 t -MD 2029.0 Ft -TVD Casino Size and Description: 113-3/8" 68n/Ft L-80 BTC • Strks psi Min psi Strks psi Min psi 0 50 0 3100 1 40 0.00 900 Casing Test Pressure IntegrltvTest -2-75 3100 -2-7o 0.25 900 Mud Weight: 10.0 ppg Mud Weight: 9.4 ppg Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 1 .D Lb/100 Ft2 Test Pressure: 2500.0 psi Rotating Weight: fit# Lbs Rotating Weight: F Lbs Blocks/Top Drive Weight: 60000.0 Lbs Blocks/Top Drive Weight 60000.0 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 2.8 bbis Estimates for Test: 896 psi 1 bbls •' • EMW Leak off Pressure + MuaWe1igW = 9oo + 9 4 T 15 Secona�_ 0.052 x TVD 0.052 x 2003 Shut-in Pressure, psi EMW at 2117.95 Ft-MD_(2003 Ft -TVD) = 18.0 ppg 900 4 _7175 -6-250 2 3100 -3-775- 0.50 900 3 31 00 4 170 1.00 890 8 450 4 3100 5 240 1.50 880 10 525 5 31 0 6 300 2.00 870 12 730 6 3100 7 370 2.50 860 14 950 7 3100 8 440 3.00 850 16 1075 8 3100 9 510 3.50 840 8 1200 -9-710-0 10 580 4.00 830 20 1300 10 3 10-5 11 640 4.50 820 22 1400 15 3100 12 720 5.00 820 3500 a000 zsoo K z000 a i W 1500 o. ,000 500 0 Lost 0 psi during test, JhvF Ili 1, 01 fYe 24 1550 20 3100 13 780 5.50 810 261 1675 25 3100 14 830 6.00 800 28 1825 30 3100 15 900 6.50 790 30 1975 7.00 780 32 2125 7.50 770 34 2275 8.00 760 36 2450 8.50 750 38 2600 9.00 740 40 2775 9.50 740 42 2925 10.00 740 44 3100. o 1 2 3 n s Barrels CASING TEST BLEAK -OFF TEST o s 10 ,s zo zs ao Shut -In time, Minutes o PIT Point o ume PUm ed o ume Bled Back o ume Pum ed o ume Bled Back 5 5 S S Comments: Tested casing with 10.0 DrilPlex mud 05:09 Hrs 9/15/18 Performed FIT with 9.4 L ND Mud 11:30 Hrs 9/15/18 MT6-06 Surface Casing - Test-FIT.xlsx Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-06 Rig: Doyon 19 Date: 9/23/2018 Drilling Supervisor: R. Reinhardt / B. Finkbiner Pump used: Mud Pump Volume Input 'W 0.1000 Bbls/Strk ' Pump Rate: 0.50 Bbl/min Integrity Test __._._...-__._......__........_.-...._..____Barrels Type of Test: Annulus Leak Off Test for Disposal Adequacy ♦ ! Pumping down annulus. 'Wasmg Test Pressure Hole Size: 12-1/4" Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:j 37.01 Ft 2117.0 Ft -MD 2003.0 Ft -TVD 9316.0 Ft -MD 6468.0 Ft -TVD 2eSin4 Size and Description: :13-3/8" 68#/Ft L-80 BTC Bbls psi Min psi Bbls psi Min psi Q 0 0 0 0.00 Changes for Annular Adequacy Test Pressure IntegrityTest Enter outer casing shoe test results in comments Mud Weight: 10.4 ppg Casing description references outer casing string. Inner casing OD: 9.6 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg Estimates for Test: 479 psi 0.9 bbls EMW = Leak -off Pressure + Mud Weight = 484 + 10.4 PIT 15 Second 0.052 x TVD 0.052 x 2003 Shut-in Pressure, psi EMW at 2117 Ft -MD (2003 Ft -ND) = 15.0 Fill in FIT Columns =_> 1000 Lu m 500 - w w � a 0 o z < s a 10 12 14 o 5 ,o s 20 zs 30 Barrels Shut -In time, Minutes CASINGTEST BLEAK-OFFTEST o PIT point 2 1 0.5 32 0.25 4 2 1 65 0.50 6 3 1.5 112 1.00 8 4 2 160 1.50 10 5 2.5 210 2.00 12 6 3 252 2.50 14 7 3.5 295 3.00 16 8 4 338 3.50 18 9 4.5 379 4.00 20 10 5 420 4.50 22 151 1 5.5 460 5.00 24 20 6 4961 5.50 26 1 25 6.5 5261 6.00 281 1 30 7 474 6.50 30 7.5 464 7.00 32 8 467 7.50 34 8.6 474 8.00 36 9 480 8.50 38 1 1 9.5 478 9.00 40 10 482 9.50 10.5 10.00 11 11.5 12 12.5 Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back Bbis I I jBbIs I S bols Comments: Pumped 10 bbls 10.4 ppg LSND for LOT, 300 bbls H2O water flush, 85 bbls diesel freeze protect. 13-3/8" Shoe FIT = 18.0 ppg on 9/15/18 Used Ball Mill injection pump #2 191TO-06 A, ounundiy Time Log & Summary Report [AOGCC] MT6-06 Well Name: MT6-06 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 9/10/2018 Rig Release :1012212018 Time Log Dur Start Depth End Depth Tana P Start Time End Tme (ho (ftKB) (ftKB) Phase Op Cme AMdyCale -T-X Operation 9/13/201817,45 91131201821:15 3.50 2,118.0 2,118.0 SURFAC CEMENT CMNT P Dowell pump .9 bbls H2O & PT to 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 361.7 bbls 11.0 ppg 1.9211 yield LiteCRETE lead cement and 69.9 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 3 - 5 bpm. Drop top plug. Dowell pump 20.1 bbls H2O. Rig displace with 284.7 bbls / 2,839 stks 10 ppg DrillPlex with 8 bpm 1740 psi. Reduce pumps to 3 bpm /400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. FIC good. CIP @ 21:07 Hrs. Calculate 99 bbis good cement to surface. Full returns during cement job. 9/132018 21:15 9/14/2018 00:00 2.75 0.0 0.0 SURFAC CEMENT RURD P Rig down cement hose, volant CRT, back off landing it and drain riser. Lay down landing it, remove bushings and dean dnp pan. MU stack washer and flush stack with black water. Lay down stack washer and blow down top drive 9/14201.8 00:00 9/142018 04:00 4.00 0.0 0.0 SURFAC CEMENT NUND P N/D riser & N/D starting head. SIMOPS - Clean pollution pan. RID flow line drains, bleeder lines & pull mouse hole. 9/142018 04:00 9/142018 05:00 1.00 0.0 0.0 SURFAC WHDBOP NUND P NIU well head & test void t/1000 psi f/10 min good. CPA] witness test and verification of alignment 9/14201805:00 9/141201806:00 1.00 0.0 0.0 SURFAC WHDBOP NUND P N/U BOPE 9/142018 06:00 9/14/2018 08:30 2.50 0.0 0.0 SURFAC WHDBOP MPDA P N/U MPD equipment, MPD damp, orbit valve, flow box. Drain lines. Hole fill & bleeder lines. 9/142018 08:30 9/14/2018 10:00 1.50 0.0 0.0 SURFAC WHDBOP NUND P N/U kill line & NIU accumulator lines from post annual inspection. 9/14/2018 10:00 9/14/2018 11:00 1.00 0.0 0.0 SURFAC WHDBOP MPDA P NIU MPD lines, Katch Kan, & 1502 lines. 9/14/2018 11.00 9/14/2018 12:30 1.50 0.0 0.0 SURFAC WHDBOP NUND P Tighten BOPE ram doors. Clean & dear mezz of tools & equipment. Charge accumulator & check for leaks. Set 5" test it & function rams (good). L/D test jt & function blinds (good) 9/14201812:30 9/14201814:00 1.50 0.0 0.0 SURFAC WHDBOP MPDA P Set MPD test cap. Test MPD system. Fluid leaking from lo-trq. C/O to-trq. Test MPD system to 250 psi for 5 min & 1200 psi for 10 min on chart (good). Remove MPD test plug & install trip nipple. 9/14201814:00 9/14201816:00 2.00 0.0 0.0 SURFAC WHDBOP RURD P Install 5" test joint. RN BODE test equipment Fill trip nipple & lines w/H20. Fill choke/kill lines. Perform shell test. 2500 psi on annular & 5000 psi on upper pipe rams (3.5" x 6" - good) 9/142018 16:00 9/14/2018 17:30 1.50 0.0 0.0 SURFAC WHDBOP WAIT T Stand by for Austin McLeod (AOGCC). SIMOPS: Loading 9-5/8" csg and HWDP in pipe shed. 9114201817:30 9114201822:30 5.00 0.0 0.0 SURFAC WHDBOP BOPE P Test ROPE w/5 test joint. Annular for 5 min/ 2500 psi 2500 psi 10 min, Remaining test 250 psi for 5 min / 5000 psi for 10 min. 4" Demo, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-112" X 6" VBR's & blind rams, 5" Dad/FOSV, HCR I Man choke/kill, Accumulator test, Initial 2,950 psi, final 1,450 psi, tat 200 psi recharge = 30 sec's, full recharge = 161 seconds. Nitrogen Bottles x4 =2150 psi. Gas alarms and PVT alarms tested. Draw down on chokes 1/1100 psi. AOGCC Austin McLeod witness test, BLM Mutasim Elganzoory waived witness. 9/14/2018 22:30 9/142018 23:00 0.50 0.0 0.0 SURFAC WHDBOP RURD P Blow down and rig down test equipment 9/14/201823:00 9114/201823:30 0.50 0.0 0.0 SURFAC WHDBOP RURD P Pull test plug and set 12-3/8" ID wear bushing. 9/14/2018 2330 9/152018 00:00 0.50 0.0 0.0 1 SURFAC CEMENT SHAH P Mobilize BHA and equipment to the rig floor 9/152018 00:00 9/15/2018 00:30 0.501 0.0 0.0 1 SURFAC I CEMENT RURD P R/U Baker BPA 9/15/2018 00:30 9/15/2018 02:30 2.00T 13.0 622.0 1 SURFAC ICEMENT SHAH P M/U 12-1/4" BHA #2 as per Baker reps to 622' Page 3125 ReportPrinted: 1/32019 Time Log & Summary Report [AOGCC] MT6-06 Well Name: MT6-06 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 9/10/2018 Rig Release :10/22/2018 Time Log SaM1 Tim. End Tlme i (hr) Sart Depth Ova) End Depth (1I1<81 phase op code Adhity ewe-T-x Time P oind n 9/21/2018 00:00 9/212018 0045 0.75 2,116.0 2,034.0 INTRMI CASING OWFF P Rack back one stand of DP. Monitor well. SFight- drop in fluid level. Blow down TD. 9211201800:45 9211201801:15 0.50 2,034.0 1,936.0 INTRMI CASING TRIP T Attempt to POOH on elevators from 2034'MD to 1 900'MD. Observe 25k overpull.and swabbing. RIH to 1936' MD 9/21/2018 01:15 921-f201803. 15 2.00 1,936.0 1,372.0 INTRMI CASING BKRM P BROOH from 1938' MD to 1372' MD. 8OD-900 gpm, 1760-2280 psi. 120 rpm, 2.5k tq. Well bore unloaded at 1800' MD. Pump 35 bbl 11.5 ppg weighted sweep. 20% cutting increase on sweep return. 921/2018 03:15 9/212018 04:45 1.50 1,372.0 615.0 INTRMI CASING PMPO P Attempt to POOH. Swabbing. Pump OOH from 1372' MD to 615' MD. 500 gpm, 700 psi. 921/201804:45 9121201805,00 0.251 615.0 615.0 1 INTRMI CASING UW -FF P Monitor well. Static. Function rams. 9212018 05:00 9212018 06:15 1.25 615.0 193.0 INTRMI CASING PMPO P Attempt to POOH. Swabbing. Pump OOH from, 615' MD to 193' MD. 500 gpm, 650 psi. 9/212018 06:15 9/212018 08:30 2.25 193.0 0.0 INTRMI CASING BHAH P Blow down TD. Lay down BHA as per Baker DD. Calc disp=98.54 bbls Act disp=356.5 bbls for trip. 9121201808:30 921201809:00 0.50 0.0 0.0 INTRMI CASING WWWH P Make up stack washing tool.Flush stack. 15 bpm, 250 psi, 20 rpm, 1.5k tq. 9/21/2018 09:00 921201.8 09:30 0.50 0.0 0.0 INTRMI CASING BHAH P Blow down mud line. Clean and dear rig floor. 9/212018 09:30 9/212018 10:00 0.50 0.0 0.0 INTRMI CASING BOPE P Drain BOPS. Pull wear ring and set test plug. 9/21/2018 10:00 921/2018 11:30 1.50 0.0 0.0 INTRMI -EASING TOPE P PJSM-Change out upper pipe rams to 9 5/8". Sim-ops/ Mobilize CRT, bail extensions and elevators to rig floor and rig up. 9/212018 11:30 91212018 12:30 1.00 0.0 0.0 INTRMI CASING BOPE P Set test plug. Rig up test equipment. Test annular preventer to 2502500 psi and upper pipe rams to 250/3500 psi. Low pressure tests were for 5 minutes each and high pressure tests were for 10 minutes each. 921201812:30 9211201813:00 0.50 0.0 0.0 INTRMI CASING BOPE P Pull test plug, set thinwall wear ring. 97121-1201813 00 W112018-13 30 0.50 0.0 0.0 INTRMI CASING RURD P Rig up to run 9 5/5" casing. 9212018 13:30 921/2018 20:00 6.50 0.0 2,565.0 INTRMI CASING PUTB P PJSM-Make up shoe track. Thread lock to pin of #5. Pump through shoe track and check floats. Good. Continue to pick up and RIH with 9 5/8" 40# TXP-HS casing to 2565' MD as per detail.Observe loss of SO weight PU wt 150k SO wt120k. 9/212018 20:00 9/21/2018 20:30 0.50 2,565.0 2,585.0 INTRMI CASING ZiRC Break circulation. Wash down from 2565' MD to 2577' MD. Stage up to 4.5 bpm 300 psi while working pipe. Attempt to wash past 2577' MD multiple times. Tum pipe 90° right and wash down to 2585' MD. 9/21201.8 20:30 9/212018 23:30 3.00 2,585.0 4,038.0 INTRMI CASING PUTB P Continue to pick up and RIH with 9 5/8" 40# TXP-HS casing from 2585' MD to 4038' MD as per detail. 9/21/201823:30 9122/201800:00 0.50 4,038.0 4,038.0 INTRMI CASING CIRC P CBU. Stage pump up to 6 bpm. 160 psi. Reciprocate from 4038' MD to 3997' MD. PU wt 175k SO wt 150k. Heaviest mud weight out 10.7 ppg T/01-201800 00 9222018 00:30 0.50 4,038.0 4,038.0 INTRMI CASING CIRC P CBU. 160 psi. Reciprocate from 4038' MD to 3997' MD. PU wt 175k SO wt 150k. Heaviest mud weight out 10.7 ppg. 922/2018 00:30 9/222018 05:15 4.75 4,038.0 6,507.0 INTRMI CASING PUTB P Continue to pick up and RIP with 9 5/8" 40# TXP-HS casing from 4038' MD to 6507' MD as per detail. PU wt 240k SO wt 185k 922/2018 05:15 9/22/2018 07:15 2.00 6,507.0 6,057.0 INTRMI CASING CIRC P CBU 1 1/2x. 270 psi. Reciprocate from 6507' MO to 6467' MD. PU wt 240k SO wt 195k. Heaviest mud weight out 10.6+ ppg. Page 6125 ReportPrinted: 113/2019 Time Log & Summary Report [AOGCC] MT6-O6 Well Name: MT6-06 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 9/10/2018 Rig Release : 10/22/2018 Time Log Start Ti. Ertl Tune Our (hr) Stan Deph (W(9) End Depth ("s) Phase Op Cope Actevdy 000 Tvn.P -T-X 0peretion 9/221201807:15 9122r201815:00 7.75 6,057.0 10,278.0 INTRMI CASING PUTB P Confinue to pick up and RIH with 9 518" 40# TXP-HS TN80, TXP L80 and HYD 563 L80 casing from 6507' MD to 10278' MD as per detail. 254 its in hole plus X -O and pup it. SO wt 225k 9!22/2018 15:00 9/22/2018 15:45 0.75 18278.0 40,316.0 INTRMI CASING HOSO -07 Make up hanger and landing joint, wash down @ 1.5 bpm, 340 psi. Land hanger and stay landed. (Note, very tight tolerances through stack and thin wall wear ring, Reciprocation would be very risky) Final SOW=225k. 9122/201815:45 W/-221201820 00 4.25 10,316.0 10,316.0 INTRMI CEMENT CIRC Circulate and condition mud for cementing. Stage pump up from 1.5 bpm 340 psi to 8 bpm 400 psi. Heaviest mud weight out 10.8 ppg. 9!222018 20:00 9/22!2018 2030 0.50 10,316.0 10,316.0 INTRMI CEMENT TURD Shut down, OWFF static. Blow down top drive, JPSLB remove mud saver valve from Volant CRT. Rig up cement hose and 1502 equipment to cement line. 9/2201820:30 /2 9/2212018 22:00 1.50 10,316.0 10,316.0 INTRMI CEMENT CMNT flood lines with 5 bbl water. Pressure test to 4000 psi, good. SLB pumped 60 bbl 11.5 ppg mud push. Shut down and drop bottom plug. Mix and pump 39.4 bbl 12.2 ppg lead cement @ 3.7- 4.7 bpm. Mix and pump 53 bbls 15.8 ppg tail cement @ 2.5-4.2 bpm. Shut down and drop NR top plug and HE top plug. Kick out with 20 bbl water. 9/22/2018 22:00 9/23/2018 00:00 2.00 10,316.0 10,316.0 INTRMI CEMENT CMNT P Rig displace cement with 10.4 ppg LSND @ 8 bpm, ICP=430 psi, FCP @ 8 bpm=880 psi. Slowed pump to 3 bpm, 600 psi @ 7230 stks away. Bump plugs at 7491 stks. Pressure up to 1100 psi and hold for -5 mins. Bleed offand check floats. Good. CIP at 23:34 him 9/23/2018 00:00 9/23/2018 0030 0.50 10,316.0 10,316.0 INTRMI CEMENT OWFF P Monitor well. Static. Sim-ops/Rig down CRT 9723/201800:30 9/23/201801:00 0.50 10,376.0 0.0 INTRMI CEMENT RURD P Lay down landing joint. Drain BOPE, 9113/2018 01:00 9/23/2018 03:00 2.00 0.0 0.0 INTRMI CEMENT W WSP P Pull thin wall wear ring. Set 9-5/8" packoff and test to 5000 psi for 10 minutes, CPAI witnessed - good. 9/23/2018 03:00 912311018 05:30 2.50 0.0 0.0 INTRMI CEMENT NUND P PJSM-Lay down mousehole Lay down trip nipple, rig down flow box, turnbuckles, mud bucket lines, bleeder and hole fill line. Break choke connection. Rig down MPD package. Break BOPEtwellhead connection. 91232018 05:30 9113/2018 09:00 3.500.0 0.0 INTRMI CEMENT NUND P Nipple up 7" casing spool and ROPE. Reposition grease flanges on wellhead as per FMC. 91232018 09:00 923/2018 10:00 1.00 0.0 00 INTRMI CEMENT TOPE -07 PJSM-Change out upper pipe rams to 4 112" x T' VBR's 9/23/2018 10:00 9/23/2018 13:30 3.50 0.0 0.0 INTRMI CEMENT NUND P Continue to rig up flow line, flow box, mud bucket lines, tip nipple, service lines and MPD lines. Secure drip pan. Install mouse hole. Rig up test equipment Sim-ops/Rig up circ lines for annular LOT. Perform flush and freeze protect.. Pump 10.5 bbls water for LOT. Flush annulus with 300 bbls water follwed by 85 bbls diesel for freeze protect 3232018 13:30 9/23/2018 14:30 1.00 0.0 0.0 INTRMI WHDBOP RURD P Set test plug. Rig up to test ROPE, fill stack, choke,, kill lines and choke manifold with water. Purge air from system. Page 7125 ReportPrinted: 113/2019 Cement Detail Report MT6-O6 String: Surface Casing Cement Job: DRILLING ORIGINAL, 9110/201800:00 Cement Details Description Surface Casing Cement 19/13/201817 Cementing Start Date 45 Cementing End Dale 9/13@018 21:15 Wellbore Name MT6-06 Comment Cement Stages Stage # 1 Description Surface Casing Cement jobjectiveDepth (ftKB) Cement Surface Casing 37.1 Bottom Depth (ftKB) 2,118.0 Fuii Return? No Vol Cement... 99.0 Top Plug? Yes Btm Plug? Yes q Pump Ind (bbUm... 5 q Pump Final (bbl/ 3 q Pump Avg (ball... 4 P Pump Final (psi) 400.0 P Plug Bump (psi) 1,000.0 Reelp? 1 Yes Strake (ft) 120.00 Related? No Pipe RPM (rpm) Tagged Depth (ftKB) 2,017.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) Drill 1121/4 Out Diameter (in) Comment 99 bbis of 11.0 lead cement to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 37.1 Est Btm (ftKB) 1,618.5 Amoum (sacks) 1,020 Gass LiteCRETE V01ume Pumped (bbl) 361.7 Yield (ft/aaek) 1.92 Mix H20Ratio (gal/sa... 6.87 Free Water (%) 1 Density (Ib/gal) 11.00 Plastic Viscosity (CP) 85.1 Thickening Time (hr) 5.33 Cmprstr 1 (psi) Additives Additive Type Concentration Conic Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,618.5 Est Bi (ftKB) 2,118.0 Amount (sacks) 328 Class Volume G 69.9 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gaUsa... 5.12 Free Water (%) Density (ibigal) 15.80 108.5 Plastic Viscosity (GP) Thickening Time (hr) CmprStr 5.45 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 113/2019 Cement Detail Report MT6-06 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description Intermediate Casing Cement Cementing Start Date 9/22/2018 20:30 Cementing End Date 9/222018 23:34 lWellbore Name MT6-06 Comment Full returns through job, bumped plugs, floats held. Cement Stages Stage # <Stage Number?> Description Intermediate Casing Cement Objective Cement Intermediate casing Top Depth (ftKB) Bottom Depth (ftKB) 9,281.0 10,326.0 Full Return? Yes Vol Cement.... Top Plug? Yes son Plug? Yes O Pump Inn (bbl/m... 4 Q Pump Final (Will....0 3 Pump Avg (bbl/... '6 P Pump Final (psi) P Plug Bump (psi) 580.0 1,100.0 Rectp? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Bumped plugs. Floats held. Cement Fluids & Additives Fluid Fluid Type Intermediate Lead Cement Fluid Description Estimated Top (ttKB) 9,281.0 Est atm (ftKB) 9,816.0 Amount (sacks) 95 Class G Volume Pumped (bbl) 39.0 Yield (ft(sack) 2.31 Mix H2O Ratio (gagsa... 13.09 Free Water I%) Density (Ib/gal) 12.20 Plastic Viscosity (CP) 12.6 Thickening Time (hr) CmprStr i (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Intermediate Tail Cement Fluid Description Estimated Top (111(8) 9,$16.0 Est Bum (ftKB) 10,326.0 Amount (sacks) 256 Class Volume G Pumped (bbl) 53.0 Yield (Wlsack) 1.16 Mix H2O Ratio (gal/sa... 5.08 Free Water I%) Density (Ib/gal) 15.80 156.1 Plastic Viscosity (cp) Thickening Time (hr) Cmpstr t (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 1/312019 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-04 Rig: Doyon 19 Date: 10/26/2018 Drilling Supervisor: R. Bjorhus /A. Dorr Pump used: n2 Mud Pump V Type of Test: casing Shoe Test LOT/FIT Pumping down T g p g annulus and DP. V Hole Size: 12-1/4" Casing Shoe Depth Hole Depth RKB-CHF: 36.1 Ft I 2046.0 Ft-MD 2029.0 Ft-TVDI 2077.0 Ft-MD 2058.0 Ft-TVD Casing Size and Description: 13-3/8" 68#/Ft L-80 3TC V Volume Input strokes 'V Volume/Stroke 0.1000 Bbls/Strk ' Pump Rate: 0.50 Bbl/min asmg Test Pressure Integrity est Pumping Strks psi Shut-in Min psi Pumping Strks psi Shut-in Min psi 0 0 0 2500 1 301 0.00 840 Casing Test PressurelntegrityTest 2 150 1 2500 2 40 0.25 820 Mud Weight: 10.0 ppg Mud Weight:10.5 ppg Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 11.0 Lb/100 Ft2 Test Pressure: 2500.0 psi Rotating Weight: Lbs Rotating Weight: /an#i Lbs Blocks Top Drive Weight: 60000.0 Lbs Blocks/Top Drive Weight 60000.0 Lbs Desired PIT EMW: 18.5 ppg Estimates for Test: 2.7 bbls Estimates for Test: 844 psi 0.9 bbis �-1 V EMW =Leak-off Pressure + Mud Weight = _ 845 IT 15 Second 0.052 x TVD 0.052 x 2029 + 10.5 Shut-in Pressure, psi EMW at 2046 Ft-MD (2029 Ft-TVD) _ 18.5 ppg 820 0000 Lost 25 psi during test, cId- of zsoo 2000 w K � (a 7500 W a. 1000 500 -amfti- M 0 o + 2 s 4 o s 10 15 20 25 ao Barrels Shut-In time, Minutes CASING TEST BLEAK-OFF TEST o PIT Point 4 300 2 2500 3 60 0.50 800 6 450 3 2500 -4-100 1.00 760 8 600 4 2500 5 150 1.50 720 10 750 5 2500 -6-200 2.00 670 12 910 6 2500 7 270 2.50 640 14 1020 7 2500 -8-355 3.00 600 16 1160 8 2500 9 420 3.50 570 18 1300 9 2500 10 500 4.00 550 20 1450 10 2500 11 550 4.50 530 22 1600 151 2475 12 600 5.00 520 24 17501 20 24751 13 680 5.50 500 26 1900 25 2475 14 740 6.00 500 28 2050 30 2475 15 790 6.50 500 30 2200 16 845 7.00 495 32 2350 7.50 490 34 2500 8.00 480 8.50 480 9.00 470 9.50 470 10.00 465 Volume Pum ed Volume Bled Back Volume Pumped Volume Bled Back s s s s Comments: Tested casing with 10.0 DrilPlex mud 20:30 Hrs 10/26/18 Performed FIT with 10.5 LSND Mud 03:45 Hrs 10!27/18 Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-04 Rig: Doyon 19 Date:- _ Volume Input 1,1111i Bbls/strk ♦ Pump Rate: _1-1/1/2018 Drilling Supervisor: K. Harding / A. CorrPump used: Other -See Comments 'Barrels Type of Test: Annulus Leak Off Test for Disposal Adequacy IV Pumping down 'annulus. W Hole Size: 12-1/4• wF Casing Shoe Depth Hole Depth 0.301 am/mio Casing Test Pressureintegrity Test Pumping Shut-in Pumping Shut-in RKB-CHF: 36.5 Ft I 2046.0 Ft -MD 2029.0 Ft -TVD 6720.0 Ft -MD 6580.0 Ft -TVD Casing Size and Description: 13-3/8" 68#/Ft L-80 BTC Bbls I psi Min psi Bbls psi Min psi 0 0 0 0 0.00 400 Chanqes for Annular Adequacy Test Pressure IntegritvTest Mud Weight: 10.5 ppg Inner casing OD: 9.625 In. Desired PIT EMW: 18.5 ppg Estimates for Test: 844 psi 1.2 bbls 2 4 1 2 -0.5-50 1 100 0.25 400 0.50 390 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. 6 3 -1.5-200 1.00 390 8 4 2 300 1.50 390 10 5 2.5 390 2.00 380- 12 6 3 480 2.50 370 14 7 3.5 560 3.00 360 16 8 3.7 580 3.50 360 =eai 1000 Lu W N 500 U o_ a 0 0 off Pressure :FMud vveight= 2046 Ft -MD (2029 Ft 57 + 10.5 PIT 15 Second Shut-in Pressure, psi 18 9 -4-560 4.00 360 0.052 EMW x TVD at 0. 5- 229 -TVD) = 15.9 20 10 4.5 540 4.50 360 400 22 15 5 550 5.00 350 24 1 201 1 5.5 450 5.50 350 26 25 61 4301 6.00 350 28 30 30 6.5 4201 6.50 350 7 420 7.00 350 32 7.5 410 7.50 350 34 8.00 350 36 8.50 350 38 9.00 350 40 9.50 350 10.00 350 2 �CASNc a Barrels TEST s e 10 -FREAK-OFF 12 TEST 1a 0 5 10 15 20 25 30 Shut -In time, Minutes o PIT PointPum Volume ed Volume Bled Back Volume Pum ed Volume Bled Back s s s s Comments: Pumped 7.5 bbls 10.6 ppg LSND for LOT, 300 bbls H2O water flush, 83 bbls diesel freeze protect. 13-3/8" Shoe FIT = 18.5 ppg on 10/26/18 Used Ball Mill injection pump #1 Summary Time Log & Summary Report [AOGCC] MT6-04 Well Name: MT6-04 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 10/23/2018 Rig Release: 11/19/2018 Time Log Our Start Depth End Depth TvneP Start Time End Time (hr) (N®) (VSB Phase Op Code ActivityCode -FX Operation 1024/2018 10/24/2018 0.25 2,047.0 2,057.0 SURFAC DRILL DDRL P Drill ahead f/2,047' to TD of 2,057' MD 12,039' 11.00 11:15 TVD, ADT .3 Hm, 900 gpm, 2500 psi, PIU wt 112 k, SIO wt 112 k, ROT wt 110 k, 60 rpm, Odg Trq 4 / OBT 3 k Kt/lbs. 102412018 10242018 0.50 2,057.0 2,057.0 SURFAC CASING CIRC P Pump 40 bbl nut plug sweep drill zone sweep 11:15 11:46 w/900 gpm, 2490 psi, 60 rpm, 1.5 k trq 1024/2018 10/24/2018 2.75 2,057.0 1,777.0 SURFAC CASING BKRM P Pump up final survey. BROOH 12,057'to 1,777' 11:45 14:30 & circ hole clean for w/900 gpm, 2490 - 2340 psi, 60 rpm, 1.5 k trq. Pumped 3 40 bbl nut plug drill zone sweeps. 10/24/2018 10/24/2018 0.50 1,777.0 1,777.0 SURFAC CASING SRW P Gyro survey @ 613'& 866' 1430 15:00 10/24/2018 10/24/2018 2.00 1,777.0 367.0 SURFAC CASING TRIP P POOH on elevators f/1,777'to 367' 15:00 17:00 10/24/2018 1024/2018 0.25 367.0 367.0 SURFAC CASING OWFF P F/C(static)-SIMOPS-PJSM on BHA 17:00 17:15 10/24/2018 1024/2018 3.25 367.0 0.0 SURFAC CASING BHAH P Rack back HWDP, Jars & NMFC. LID BHA as 1715 20:30 per Baker reps. (Bit, motor & string stab significantly balled up) 10/24/2018 10/242018 0.50 0.0 0.0 SURFAC CASING BHAH P Clean &clear floor of BHA tools & equipment. 20:30 21:00 1024/2018 10/24/2018 1.75 0.0 0.0 SURFAC CASING RURD P Mobilize casing tools & equipment to rig floor. 21:00 22.:45 R/U to run casing. R/U Volant & casing tongs, slips & elevators. 10242018 1025/2018 1.25 0.0 122.0 SURFAC CASING PUTB P M/U 13-3/8" 68" BTC shoe track to 122' 22:45 00:00 1025/2018 102512018 3.50 122.0 786.0 SURFAC CASING PUTB P Cont- to make up shoe track & check floats 00:00 03:30 (good). RIH w/13-3/8" 684 L-80 BTC/TXP casing to 786'. Observe slack off start to diminish. (SO wt 75k) 102512018 10252018 0.50 786.0 786.0 SURFAC CASING CIRC P Circ B/U w/6 bpm 1100 psi 03:30 04:00 1025/2018 10/252018 1.50 786.0 1,262.0 SURFAC CASING PUTB P RIH w/13-3/8" 68# L-80 BTC/-XP casing 1/786' 04:00 05:30 to 1,262' (SO wt 110 k) 10252018 1025/2018 1.25 1,262.0 1,262.0 SURFAC CASING CIRC P Circ B/U @ base of permafrost w!7 bpm / 210 05:30 06:45 psi 1025/2018 10/25/2018 3.00 1,262.0 2,008.0 SURFAC CASING PUTB P RIH w/13-3/8" 68# L-80 BTC?XP casing 1/1,262' 06:45 09:45 to 2,008' (SO wt 100 k) 10/25/2018 10/262018 0.25 2,008.0 2,046.0 SURFAC CASING HOBO P M/U landing jt & land rasing on hanger @ 2,046' 09.45 10:00 10/25/2018 10/25/2018 3.00 2,046.0 2,046.0 SURFAC CEMENT CIRC P Circ & cond mud for cement job w/8 bpm / 180 10:00 13:00 psi. Reciprocate pipe. (PU wt 165 k / SO wt 155 k) 1025/2018 1025/2018 0.50 2,046.0 2,046.0 SURFAC CEMENT RURD P R/U cement lines. Break cir thru cementing lines. 13:00 13:30 FIC (static) 10258018 10/25/2018 3.50 2,046.0 2,046.0 SURFAC CEMENT CMNT P Dowell pump 1 bbl H2O & PT to 3500 psi (good). 13:30 17:00 Dowell pump 100 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 297.5 bbls 11.0 ppg 1.92 ft3/sx yield LiteCRETE lead cement and 72 We 15.8 ppg 1.16 ft3/sx yield tail cement @ 3 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 273 bbls / 2,730 stks 10 ppg DrillPlex with 8 bpm / 465 psi. Reduce pumps to 3 bpm /400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. FIC good. CIP @ 16:54 Hm. Calculate 154 bbls good cement to surface. Full returns during cement job. 1025/2018 10/252018 2.50 0.0 0.0 SURFAC CEMENT RURD P Flush riser w/black water. R/D Volant & casing 1700 19:30 running tools & equipment. LID landing jL 10/25/2018 10/25/2018 2.00 0.0 0.0 SURFAC CEMENT NUND P KID surface riser easy. NIL) speed lock head 1930. 21:30 1 adaptor. SIMOPS -clean pits. Page 2117 ReportPrinted: 1/3/2019 Time Log & Summary Report [AOGCC] MT6-04 Well Name: MT6-04 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 1 012 312 01 8 Rig Release: 11/1912018 Time Log Dur Start Depth End Depth Tint. P Start Time End Tme (bp (ftKB) (XKB) Phase Op Cade A ,,ity Code -T-X Operation 10/30/2018 10130/2018 2.50 0.0 0.0 INTRMI CASING W W WH P Pull wear ring. M/U Johnny Wacker & flush stack 17:00 19:30 2X. SIMOPS - stage casing equipment, Electrician replace camera in derrick. 10/30/2018 10/30/2018 1.75 0.0 0.0 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 9 5/8". Set 19:30 21:15 test plug & R/U to test ROPE. SIMOPS - Mobilize casing running tools to rig floor. 10/30/2018 10/30/2018 0.75 0.0 0.0 INTRMI CASING BOPE P Test annular preventer to 250 for 5 min 12500 21:15 22:00 psi for 10 min. Test upper pipe rams to 250 for 5 min //3500 psi for 10 min. 10/30/2018 10/30/2018 1.00 0.0 O.0 INTRMI CASING BOPE P R/D testing equipment. Set 13.125" wear Ong. 22:00 23:00 10/30/2018 10/31MIS 1.00 0.0 80.0 INTRMI CASING PUTS P PJSM on running casing. M/U 9-5/8" 40# TN -80 23:00 00:00 TXP shoe track to 80' 101312018 1O/31/2018 12.0 80.0 5,193.0 INTRMI CASING PUTS P Cont. M/U 9-518"40# TN -80 TXP shoe track 1180' 00:00 12:00 0 to 162'. Check floats (good). RIH 9-5/8" casing f/162' to 5,193'. 1[0/31/2018 10131/2018 8.75 5,193.0 7,683.0 INTRMI CASING PUTB P RIH 9-5/8" casing f/5,193'to 7,683'. Washed thru 12:00 20:45 tight hole f/6,820' to 6,875' & 7,540'to 7,683' w/2 5 bpm. 101312018 10/3112018 0.75 7,683.0 7,720.0 INTRMI CASING HOSO P M/U hanger & landing jt. Wash down w/4 bpm, 20:45 21:30 350 psi & land on hanger 7,720'. PIU wt 345 k / S/O wt 250 k. 10/31/2018 11112018 00:00 2.50 7,720.0 7,720.0 INTRMI CEMENT CIRC P Circ & cond for cement job. Stage flow rate to 8 21:30 bpm, 400 psi. Not able to reciprocate pipe due to hanger hanging up in stack. 11/12018 00:00 11/1/2018 00:15 0.25 7,720.0 7,720.0 INTRMI CEMENT CIRC P Circ & cond for cement job w/8 bpm, 400 psi. 11/12018 00:15 11/1/2018 00.30 0.25 7,720.0 7,720.0 INTRMI CEMENT RURD P Shut down, FIC static. Blow down top drive, Rig up cement hose and 1502 equipment to cement line. 11/1/201800:30 11/11201801:00 0.50 7,720.0 7,720.0 INTRMI CEMENT CIRC P Break cm; w/8 bpm, 575 psi. PJSM on cementing, 11/12018 01:00 11/1/2018 04:00 3.00 7,720.0 7,720.0 INTRMI CEMENT CMNT P Dowell pump 1.2 bbls H2O & PT to 4000 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbls 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 50.1 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbls H2O. Rig displace with 559.2 bbls (5,605 stks @ 95%) 10.5 ppg LSND with 8 bpm / 440 - 960 psi. Reduce pumps to 3 bpm / 650 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1150 psi for 5 min. Check floats. FIC good. CIP @ 3:49 Hrs. Full returns during cementjob. 11/1201804:00 11111201804:30 0.50 0.0 O.O INTRMI CEMENT OWFF P Monitor well. Static. SIMOPS - RID Volant 11/1/2018 04:30 11/1/2018 05:00 0.50 0.0 O.0 INTRMI CEMENT RURD P Cont. R/D Volant. UD landing jt. 11/12018 05:00 11/1/2018 07:00 2.00 0.0 0.0 INTRMI CEMENT WASP P FMC Pull thin wall wear ring. Set 9-5/8" packoff and test to 5000 psi for 10 minutes, CPAI witnessed (good) 11/1/2018 07:00 11/12018 09:00 2.00 0.0 0.0 INTRMI CEMENT BOPE P PJSM, C/O Upper Pipe Rams from 9-5/8" SBR to 41/." x 7" VBR. 11/1/2018 09:00 11/12018 10:00 1.00 0.0 0.0 INTRMI WHDBOP RURD P R/U to test ROPE, fill stack, choke and kill lines and choke manifold with H2O, Purge air from system. Page 5117 Report Printed: 1/3/2019 AL . - 5 ,rim Cement Detail Report MT6-04 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Surface Casing Cement Cementing Start Date 10/25/2018 13.30 Cementing End Date 10/25/2018 1700 Wellbore Name MT6-04 Comment Cement Stages Stage If 1 Description Surface Casing Cement I Objective Cement Surface Casing ITop Depth (ftKB) Bottom Depth (nKB) 138.0 2.046.6 Full Return? 1 Yes Vol Cement... 154.0 Top Plug? Yes Btm Plug? No Q Pump [nit (bbdm... 8 Q Pump Final (bbl/... 3 Q Pump Avg (bbl/... 6 P Pump Final (psi) P Plug Bump (psi) 400.0 900.0 Recip7 1 Yes I Stroke (ft) 10.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 154 bbis good cement returns to surface Cement Fluids & Additives Fluid Fluld Type Lead Cement Fluid Description Estimated Top (ftKB) 38.0 Est arm (ftKB) 1,546.0 Amount (sacks) 857 Class G Volume Pumped (bbl) 297.5 Yield (Wisack) 1.95 Mix H2O Ratio (gal/sa... 7. Free Water (°/) 1 Density, (Ib/gall 1 11.00 Plastic Viscosity (cP) Thickening Time (hr) 15.50 CmprStr 1 (psi) Additives Additive Type Concentration Cono Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,546.0 I Est Stan (nKB) 2,046.6 Amount (sacks) 348 Class G Volume Pumped (b 1) 72.0 Yield (Wisack) 1.16 Mix H2O Ratio (Stiles... 5.10 Free Water (%) Density (lblgal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 15.10 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 1/3/2019 Cement Detail Report MT6-04 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 10/2212018 07:00 Cement Details DescriptionCementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/1/20180100 11/1/201804:00 MT6-04 Comment Break cm;w/8 bpm, 575 psi. PJSM on cementing. Dowell pump 1.2 bbls H2O & PT to 4000 psi (good). Dowell pump 60 bbis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbls 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 50.1 bbls 15.8 ppg 1..16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 Ili H2O. Rig displace with 559.2 bbls (5,605 stks @ 95%) 10.5 ppg LEND with 8 bpm 1440 - 960 psi. Reduce pumps to 3 bpm / 650 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1150 psi for 5 min. Check floats. F/C good. CIP @ 3:49 Hrs, Full returns during cement job. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? awn Plug? Intermediate Casing 1000' of cement from 6,720.0 7,719.9 Yes Yes Yes Cement shoe O Pump Mit (bblim... IQ Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 6 650.0 650.0 No Nc Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill out Diameter (in) Comment Break circw/8 bpm, 575 psi. PJSM on cementing. Dowell pump 1.2 bbis H2O & PT to 4000 psi (good). Dowell pump 60 obis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbis 12.2 ppg 2.3 113/sx yield Class G lead cement and 50.1 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbis H2O. Rig displace with 559.2 bbls (5,605 stks @ 95%) 10.5 ppg LSND with 8 bpm /440 - 960 psi. Reduce pumps to 3 bpm /650 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1150 psi for 5 min. Check floats. F/C good. CIP @ 349 His. Full returns during cementjob. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est arm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 6,720.0 7,219.9 I 99 G 40.5 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gat) Plastic Viscosity (0) Thickening Time (hrl CmprStr 1 (psi) 2.30 1.3 12.20 6.20 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid DescriptionEstimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 7,220.0 7,720.0 243 G 50.1 Yield (Wlsack) Mix H2O Ratio (gal/sa... Free Water i Density (Ib/gal) Plastic Viscosity (c P) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 1 1 1 4.50 Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 1/3/2019 Note to File GMTU MT6-05 (PTD 218-045) November 6, 2018 Revised: January 8, 2019 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well MT6-05 Request ConocoPhillips requests approval increase annular disposal limit for drilling wastes in well MT6-05 from 35,000 to 70,000 barrels. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 13-3/8" surface casing shoe is set in this well at 2,014' measured depth (equivalent to -1,888' true vertical depth subsea'), near the base of a 650 -foot thick interval of claystone and siltstone 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 sandstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining claystone intervals are sufficiently thick and laterally persistent to ensure injected materials remain within the 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 likely increase in radius from 160' to about 220' from the wellbore. However, the injected fluids may reach several nearby wells that have open annuli beneath the surface casing shoe. If injected wastes reach nearby wells, competent surface casing, cement and the surrounding claystone and siltstone confining layers will ensure the injected waste fluids remain within the approved disposal interval. Discussion ConocoPhillips' application to increase the limit for annular disposal in well MT6-05 was reviewed along with the previous approval for annular disposal in that same well. The discussion that follows is based on well logs and mud logs from MT6-05 and several nearby wells.' Index maps are provided in Figures 1 and 2, below. ' Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet of 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. ' MT6-03, MT6-03PH1, MT6-04, MT6-06, MT6-08, MT6-08PH1, Lookout 1, and Lookout 2. MT6-05 Annular Disposal (Revised) Note to File January 8, 2019 Page 2 of 5 The proposed annular disposal injection interval in MT6-05 lies in the Seabee Formations within Section 6, TION, R3E, Umiat Meridian (UM) and in section 31, TI IN, R3E, UM, which is about 3,400 from the current exterior boundary of the Greater Moose's Tooth Unit. The surface casing shoes of these wells mainly lie between about -1,918' and to -2,000', near the base of a 650 -foot thick interval that is dominated by claystone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for fluids disposed in the annulus of the well (see Figure 3, below). In MT6-05, the annulus open to the disposal interval extends downward from the surface casing shoe at -1,882' to the top of cement for the 9-5/8" casing string, which is estimated to be about -6,320'. The portion of the open annulus that will most likely accept the injected waste is a 190 -foot thick interval containing several 1- to 6 -foot thick beds of sandstone and sandy siltstone that lie between -2,005' and -2,183', below the surface casing shoe (see Figure 2). The aggregate thickness of these thin, potential receptor beds is about 20'. The sandstone and sandy siltstone are separated by siltstone and claystone intervals. Beneath the disposal interval is a thick interval dominated by claystone that is continuous throughout the area. This interval will provide lower confinement for any injected wastes. Mi6Ol Surface Casing Shoes MW& LOOK 2 µ MIBgStt A3 IAi6-OSP62 M1600 Mlaoa Affaetsd Are -4 '320'Radius . LOOKOUT 1 • A1Tfi-OSPB 0' SOa Area of Review (1/4 -Mile Radius) GMTU Boundary 0 1.0 mi � MT6L8 Figure 1. MT6-05 Index Map The index map above displays trajectories for all wells currently drilled from the Greater Moose's Tooth Unit MT6 Drill Site. The locations of the surface casing shoes for all well bores are illustrated using green - colored triangles. Four wells currently lie within the V4 -mile radius area of review surrounding the planned injection interval in MT6-05: wells MT6-03, MT6-04, MT6-06, and MT6-08. I MT6-05 Annular Disposal (Revised) Note to File January 8, 2019 Page 3 of 5 Figure 2, below, presents a southeast -trending structural cross-section view of MT6-05 and nearby wells Lookout 1 (located 1.7 miles to the northwest) and the pilot hole for well MT6-03 (labeled "MT6-03PH1", and located about 0.1 miles to the southeast), which were logged to the ground surface. Resistivity measurements suggest that the base of permafrost occurs at roughly -920' in the MT6 Drill Site area, which is about 1,085' above the top of the likely disposal injection interval. wlU][VswW NW 201M30 - - -- ,T� YJ1vaNinW —_ _-- 21MW _ 0.0IIM iViViN/,V/V __.. _—_ ._ 2180181 SE WMMOPNUIPSI K CGNOOWHUL OONOOOPMLLIP3 LOOKOIITI UMTUMT805 GM MT803PH1 338FNL WM a1 FNL 3171 FR M7M 313FFEL T .11N Rery.2 E -G .a T :io N-Rm 3E -S 0 T ,10 N -R qAE-5 B 4 =a �t'' t t� —Permafrost ea ------------------ Confining Intervals ZZZZr Likely Injection Intei val i Confining Intervals t f9 - s1 --_ -------------------- I , �-318" Casing 1__________________I�-3/8"Casing Shoe - - @ 2, 014' MD _ (-1,882'TVDSS) i ,+ IjI ' Figure 2. MT6-05 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) Annular disposal in MT6-05 will not impact any commercial oil or gas accumulations. A mud log recorded in the pilot hole for nearby well MT6-03 well indicates the likely disposal injection interval contains minor amounts of gas that is predominantly methane. The shallowest oil indicator recorded while drilling the pilot hole for MT6-03 (the nearest mud -logged well) is at -2,760', which is about 580 vertical feet below the base of the likely injection interval. The mud logging geologists described this oil indicator as slow, pale, MT6-05 Annular Disposal (Revised) Note to File January 8, 2019 Page 4 of 5 straw-colored solvent cut with no associated oil staining. This description suggests the presence of only trace quantities of oil at that depth. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the affected area of the Lookout Oil Pool." This is correct: Conclusion 6 of Area Injection Order No. 40—which governs the Lookout Oil Pool—states that there are no freshwater aquifers within the Affected Area of the Lookout Oil Pool. Injected Fluid vs Affected Area Surrounding MT6-05 Wellbore (Assumptions: 26.0% porosity, 50% native fluid displacement, aggregate cylinder 20.9 high) 300 0 1 1 1 I I I I 1 I 1 I I I 10,000 15,000 20,000 25,000 30,000 35,000 40,000 45,000 50,000 55,000 60,000 65,000 70,000 Amount of Injected Fluid (barrels) Figure 3. MT6-05 Area Likely Affected by Additional Annular Injection (Assuming piston -like, radial displacement of 50% of native formation fluids) The gamma ray curve recorded in MT6-05 indicates that about 20 net feet of sandstone and sandy siltstone are present within the likely disposal interval (assuming a gamma ray well log cut-off value of 80 API). Inspection of the neutron and density porosity logs for correlative intervals in the pilot hole for nearby well MT6-03 suggests an average density porosity of about 26 percent at this depth. Based on these values, the volume of rock that will receive 70,000 barrels of injected waste material lies within a radius of about 220' from the wellbore, assuming uniform, radial, piston -like displacement of half of the native formation pore fluids (see Figures 1 and 3, above). Summary The limited volume of rock that will be affected by this proposed additional annular disposal injection contains predominantly methane gas, is situated beneath about 920' of permafrost, and is bounded above and below by continuous intervals consisting of siltstone and claystone. This disposal interval lies inside the Greater Moose's Tooth Unit, away from any external property lines, so correlative rights are not a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon MT6-05 Annular Disposal (Revised) Note to File January 8, 2019 Page 5 of 5 accumulations within or near the likely disposal injection interval. Although there are nearby wells with annuli that are open beneath the surface -casing shoe, surface casing, good surface -casing cement, and thick overlying siltstone and claystone confining layers should prevent injected fluids from migrating out of the disposal injection interval. I recommend approving the proposed annular disposal operations within GMTU MT6-05 to the limit of 70,000 barrels. Steve Davie Senior Petroleum Geologist CoAcUr T cov�,c,v r W 1-i I1 `I I Lot Annular Disposal Application — MT6-05 MT6-03 Surface.Casing Sha,'es Mr6-05 LOOKOUT 2 MT6-05L1 A \ 5 MT6-05PB2 MT6-08MT6-04 \� Affected Area'--'�'� "'220' Radius LOOKOUT 1 MT6-05PB1 0' 500' MITRE 1 0 1.0 mi MT6-O6 AOGCC Jan. 8, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permitto Drill 2180450 Well Name/No. GMTU MT6-05 FG -L- Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20771-00-00 P82' MD 17391 TVD 7886 Completion Date 7/14/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No ✓ Samples Nov Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/ RES/ NEU/ DEN, CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 29544 Digital Data 11092 8400 7/27/2018 _ Electronic Data Set, Filename: MT6-05 SCMT 29JUN2018 PASSUP30FPM_024PUC.las ED C 29544 Digital Data 7/27/2018 Electronic File: MT6-05 SCMT 29JUN2018 PASSUP30FPM_024PUC.DLIS ED C 29544 Digital Data 7/27/2018 Electronic File: MT6-05 SCMT 29JUN2018 P FIELD PRINT.PDF Log C 29544 Log Header Scans 0 0 2180450 GMTU MT6-05 LOG HEADERS ED C 29687 Digital Data 110 17392 9/19/2018 Electronic Data Set, Filename: MT6-05 Drilling Mechanics Depth Data.las ED C 29687 Digital Data 57 17391 9/19/2018 Electronic Data Set, Filename: MT6-05 LTK - Memory Drilling Data.las ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 21VID Memory- Log.cgm ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 5MD Memory Log.cgm ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 5TVD Memory Log.cgm ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK Memory Drilling - Data.dls ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Depth Log.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 2MD Memory Log.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 51VID Memory . Log.pdf AOGCC Page I of 5 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180450 Well Name/No. GMTU MT6-05 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20771-00-00 MD 17391 TVD 7886 Completion Date 7/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 LTK 5TVD Memory Log.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time - Log Runl.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time - Log Run2.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time ' Log Run3.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time Log Run4.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time - Log Run5.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time - Log Run6.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time - Log Run7.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time, Log Run8.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 Drilling Mechanics Time Log Run9.pdf ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 EOW - NAD27.pdf - ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 EOW - NAD27.txt - ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 EOW - NAD83.pdf . ED C 29687 Digital Data 9/19/2018 Electronic File: MT6-05 EOW - NAD83.txt Log C 29687 Log Header Scans 0 0 2180450 GMTU MT6-05 LOG HEADERS Log C 29689 Log Header Scans 0 0 2180450 GMTU MT6-05 LOG HEADERS ED C 29689 Digital Data 62 12037 9/19/2018 Electronic Data Set, Filename: MT6-05PB1 Drilling Mechanics Depth Data.las ED C 29689 Digital Data 57 12037 9/19/2018 Electronic Data Set, Filename: MT6-05PB1 LTK Memory Drilling Data.las ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK 21VID Memory Log.cgm ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK 51VID Memory Log.cgm AOGCC Page 2 of 5 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1 0126/2 01 8 Permit to Drill 2180450 Well Name/No. GMTU MT6-05 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20771-00-00 MD 17391 TVD 7886 Completion Date 7/14/2018 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK 5TVD Memory Log.cgm ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK Memory Realtime Drilling Data.dls ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-051361 Drilling Mechanics Depth Log.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK 2MD Memory Log.PDF ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 LTK 51VID Memory Log.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05P81 LTK 5TVD Memory Log.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-051361 Drilling Mechanics Time Log Run0l.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 Drilling Mechanics Time Log Run02.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 Drilling Mechanics Time Log Run03.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05P61 Drilling Mechanics Time Log Run04.pdf ED C 29689 Digital Data _ 9/19/2018 Electronic File: MT6-05PB1 EOW - NAD27.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05P61 EOW - NAD27.txt ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 EOW - NAD83.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 EOW - NAD83.txt ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05P81 Final Suwey.pdf ED C 29689 Digital Data 9/19/2018 Electronic File: MT6-05PB1 Final Survey.txt ED C 29690 Digital Data 62 13785 9/19/2018 Electronic Data Set, Filename: MT6-051362 Drilling Mechanics Depth Data.las ED C 29690 Digital Data 115 13786 9/19/2018 Electronic Data Set, Filename: MT6-0513132 LTK Memory Drilling Data.las ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK 21VID Memory Log.cgm ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK SMD Memory Log.cgm AOGCC Page 3 of 5 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180450 Well Name/No. GMTU MT6-05 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20771-00-00 MD 17391 TVD 7886 Completion Date 7/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK 5TVD Memory Log.cgm ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK Memory Drilling Data.dls ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 Drilling Mechanics Depth Log.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK 2MD Memory Log.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK 5MD Memory Log.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 LTK 5TVD Memory Log.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 Drilling Mechanics Time Log Run07.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 Drilling Mechanics Time Log Run08.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 Drilling Mechanics Time Log Run09.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 EOW - NAD27.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 EOW - NAD27.txt ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 EOW - NAD83.pdf ED C 29690 Digital Data 9/19/2018 Electronic File: MT6-05PB2 EOW - NAD83.txt Log C 29690 Log Header Scans 0 0 2180450 GMTU MT6-05 LOG HEADERS ED C 29791 Digital Data 10/12/2018 Electronic File: MT6-05 EOW - NAD27.pdf ED C 29791 Digital Data 10/12/2018 Electronic File: MT6-05 EOW - NAD27.bd ED C 29791 Digital Data 10/12/2018 Electronic File: MT6-06 EOW - NAD83.pdf ED C 29791 Digital Data 10/12/2018 Electronic File: MT6-05 EOW - NAD83.txt Log C 29791 Log Header Scans 0 0 2180450 GMTU MT6-05 LOG HEADERS Log C 29792 Log Header Scans 0 0 2180450 GMTU MT6-05PB1 LOG HEADERS ED C 29792 Digital Data 10/12/2018 Electronic File: MT6-05PB1 EOW - NAD27.pdf ED C 29792 Digital Data 10/12/2018 Electronic File: MT6-051361 EOW - NA027.txt ED C 29792 Digital Data 10/12/2018 Electronic File: MT6-05PB1 EOW - NAD83.pdf AOGCC Page 4 of 5 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1 0/261201 8 Permit to Drill 2180450 Well Name/No. GMTU MT6.05 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20771-00-00 MD 17391 TVD 7886 Completion Date 7/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29792 Digital Data 10/12/2018 Electronic File: MT6-05PB1 EOW - NAD83.txt ED C 29793 Digital Data 10/12/2018 Electronic File: MT6-05PB2 EOW - NAD27.pdf ED C 29793 Digital Data 1 0/1 212 01 8 Electronic File: MT6-05PB2 EOW - NAD27.txt ED C 29793 Digital Data 10/12/2018 Electronic File: MT6-05PB2 EOW - NAD83.pdf ED C 29793 Digital Data 1 0/1 21201 8 Electronic File: MT6-05PB2 EOW - NAD83.txt Log C 29793 Log Header Scans 0 0 2180450 GMTU MT6-05PB2 LOG HEADERS Well Cores/Samples Information: — - — - - Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y Production Test Intonation Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 7/14/2018 Release Date: 4/20/2018 Description Directional / Inclination Data Y Mechanical Integrity Test Information Y / NA Daily Operations Summary Y Date Comments Mud Logs, Image Files, Digital Data Y / NA Composite Logs, Image, Data Files Y Cuttings Samples Y / NA Core Chips Y / NA Core Photographs Y / NA Laboratory Analyses Y / NA Comments: 1 - -- -- - Compliance Reviewed By: Date: AIH,(/ Page 5 of 5 Friday, October 26, 2018 BAJUGHES Date: a GE company To: November 28, 2018 Al%y Bell AOGCC 333 West 7' Ave, Suite 100 Anchorage, Alaska 99501 From: 21 8045 3 Letter of Transmittal 4Q&',�'te of Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): MT6-05PB1 MT6-05PB2 MT6-05 MT6-05L1 (4) Total prints Enclosed for each well(s): RECEIVED NOV 2 9 2018 AOGCC 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soner(cDBHGE.com 218045 29791 Letter of Transmittal BATE Date: October 11, 2018 a GE company To: Meredith Guhl AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 941h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 IH -21A 1H-21AL1 1H-21AL2 1H-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 MT6-05PBi REGiVED MT6-05PB2 M76-05 OCT 12 2018 MT6-05L1 AOGCC MT6-08PB1 MT6-08 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Raebirsinghna RHGF mm ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05 50-103-20771-00 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 21804 BA ER F�UGHES a GE company ConocoPhillips Company: Conoco Phillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well MT6-05 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +N1 -S 0.00 usfl Northing: +E/ -W 0.00 usfl Easting: Position Uncertainty 0.00 usfl Wellhead Elevation: Wellbore MT6-05 Magnetics Model Name Sample Date BGGM2017 5/20/2018 Design MT6-05 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 0.00 Well MTB -05 MT6-05 Actual @ 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,543.79 usfl 317,059.98 usfl 0.00usft Declination (1) 16.50 Tie On Depth: 12,406.40 +N/-5 (usfl) 0.00 Latitude: Longitude: Ground Level: Dip Angle (1) 80.72 +E/ -W Direction (usfl) (I 0.00 320.71 BA ER UGHES 70" 15'22.964 N 151' 28'42,930 W 37.20 usfl Field Strength (nT) 57,422 6/15/2018 5: 00 04P Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConowPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lockout Pad Well: MT6-05 Wellbore: a MT6-05 Design: MT6-05 Survey Program i From To t€ (usft) (usft) I 60.26 263.26 296.26 1,957.96 2,050.54 8,894.81 8,968.80 11,028.48 11,106.00 11,358.55 11,453.90 12,406.40 12.501.75 17,362.98 Survey Data Survey (Wellbore) GYD Gyro DMS i6" (MT6-05PB1) BHGE MWD+IFR+MSA 16" (MT6-05PB1 BHGE MWD+IFR+MSA 12-1/4" (MT6-05 BHGE MWD+IFR+MSA 6x8-3/4" (MT6-0 BHGE MWD INC 6" (MT6-05PB2) BHGE MWD+IFR+MSA 6" (MT6-05PB2) BHGE MWD+IFR+MSA6 (MT605) ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MT6-05 Actual @ 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production Tool Name Description GYD-CT-DMS Gyrodata wnt.drillpipe m/s MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD -INC -ONLY (INC>10°) MWD -INC -ONLY -FILLER ( INC>10") MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Start Date 5/13/2018 5/15/2018 5/21/2018 6/4/2018 6/22/2018 6/22/2018 6/26/2018 BAER �UGHEMS Survey End Date 5/13/2018 Annotation 8/152018 5:00:04PM Page 3 COMPASS 5000.14 Build 86 Map Map ical MD Inc Azf ND TVDSS +N/4i +E/ -W OLS 'Section (usft) (% (°) (usft) (usft) (usft) (usft) Northing E sting C/100') Surve Tool Name y (ft) (ft) (ft) 36.50 0.00 0.00 36.50 -02.20 0.00 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.26 0.33 231.64 60.26 -28,44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.00 GYD-CT-DMS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 -0.36 5,945,543.27 317,059.61 0.22 -0.18 GYD-CT-DMS(1) 263.26 0.56 211.72 263.25 174.55 -1.26 -0.70 5,945,542.54 317,059.25 0.24 -0.53 GYDCT-DMS(1) 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96 1.31 -0.62 MWD+IFR-AK-CAZSC(2) 390.15 1.24 252.95 390.13 301.43 -246 -2.50 5,945,641.40 317,057.42 0.64 -0.32 MWD+IFR-AK-CAZSC(2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 1.65 MWD+1FR-AK-CAZSC(2) 577.56 3.84 299.00 577.36 488.66 0.13 -9.59 5,945,544.16 317,050.40 1.76 6.18 MWD+IFR-AK-CAZSC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 13.46 MWD+IFR-AK-CAZSC(2) 766.06 TIM 304.80 764.99 676.29 9.68 -24.57 5,945,554.26 317,035.66 1.63 23.20 MWD+IFR-AKCAZSC(2) 860.61 8.03 306.69 B58.72 770.02 17.11 34.60 5,945,561.73 317,025.81 1.12 35.15 MWD+IFR-AKCAZSC(2) 955.24 8.96 307.34 952.31 863.61 25.53 45.76 5,945,570.42 317,014.86 0.99 48.73 MWD+IFR-AKCAZ-SC(2) 1,048.71 10.08 308.87 1,044.50 955.80 35.08 -57.91 5,945,580.26 317,002.94 1.23 63.82 MWD+IFR-AKCAZSC(2) 1,143.86 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 9,945,591.88 316,989.36 1.57 81.33 MWD+IFR-AKCAZSC(2) 1,236.25 12.95 310.96 1,230.19 1,141.49 59.31 37.07 5,945,605.19 316,974.39 1.50 101.04 MWD+IFR-AK-CAZ-SC(2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,94562D.06 316,957.95 125 122.86 MWD+1FR-AK-CAZ-SC(2) BAER �UGHEMS Survey End Date 5/13/2018 Annotation 8/152018 5:00:04PM Page 3 COMPASS 5000.14 Build 86 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MT6-05 Actual @ 88.70usR (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production %G FS ConocoPhillips Company: ConomPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MT6-05 Actual @ 88.70usR (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production %G FS 8/15/2018 5: 00 04P Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDSS +NIS +El -W DLS (usft) (9 (°) (usR) (usft) (usR) (us@) Northing Ealiting (°/160') Section Survey Tool Name gnnOtBtiDn (RI lift) (R) 1,427.45 14.70 308.04 1,413.78 1,325.08 88.66 -122.08 5,945,635.38 316,940.10 0.89 145.92 MWD+IFR-AK-CAZSC(2) 1521.38 15.39 305.44 1,504.49 1,415.79 103.23 -141.62 5,945,650.42 316,920.92 1.03 169.58 MWD+IFR-AK-CAZSC(2) 1,616.89 14.91 304.96 1,596.68 1,507.98 117.62 -162.02 5,945,665.30 316,900.88 0.52 193.63 MWD+IFR-AK-CAZSC(2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 217.06 MWD+IFR-AK-CAZ-SC(2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 242.23 MWD+IFR-AK-CAZSC(2) 1,899.91 18.01 307.58 1,868.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.39 MWD+IFR-AK-CAZ-SC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 287.27 MWD+IFR-AK-CAZ-SC(2) 2,014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,810.51 0.83 305.12 MWD+IFR-AK-CAZ-SC (3) 13-3/8" X 16" 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 316.98 MWD+IFR-AK-CA7-SC(3) 2,089.52 20.21 307.93 2,04177 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 329.92 MWD+IFR-AK-CAZ-SC (3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 -301.15 5,945,774.29 316,764.37 2.55 363.49 MWD+IFR-AK-CAZ-SC (3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 331.10 5,945,798.93 316,735.00 2.78 400.98 MWD+IFR-AK-CAZ-SC (3) 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 -353.43 5,945,825.26 316,703.30 1.60 441.23 MWD+IFR-AK-CAZ-SC (3) 2,467.33 27.46 308.78 2,391.02 2,302.32 299.60 -397.30 5,945,852.94 316,670.10 0.85 483.47 MWD+IFR-AK-CAZ-SC (3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 432.25 5.945,880.75 316,635.82 2.80 526.47 MWD+IFR-AK-CAZ-SC (3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 -469.44 5,945,909.21 316,599.32 1.14 571.36 MWD+IFR-AK-CAZ-SC (3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 508.33 5,945,939.34 316,561.15 1.05 613.58 MWD+IFR-AK-CAZ-SC (3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.56 667.29 MWD+IFR-AK-CAZ-SC (3) 2,93395 32.30 307.89 2,791.22 2,702.52 444.83 587.97 5,946,002.74 316,483.03 0.12 716.61 MWD+IFR-AK-CAZ-SC(3) 3,028.87 32.99 308.00 2,871.15 2,782.45 476.32 028.35 5,946,035.20 316,443.43 0.73 766.54 MWD+1FR-AK-CAZ-SC (3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 069.28 5,946,067.97 316,403.28 0.64 817.07 MWD+IFR-AK-CAZ-SC (3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946,101.09 316,%2.09 1.33 868.51 MWD+IFR-AK-CAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 921.41 MWD+IFR-AK-CAZSC(3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946,169.49 316,276.14 0.79 975.28 MWD+IFR-AK-CAZSC(3) 3,500.89 36.47 306.40 3,25286 3,169.16 640.06 043.65 5,946,204.11 316,232.18 0.59 1.29.61 MWD+IFR-AK-CAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 388.51 5,946,238.62 316,188.14 0.74 1,08390 MWD+IFR-AK-CAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 434.17 5,946274.11 316,193.34 0.65 1,139.42 MWD+IFR-AK-CAZSC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 -982.28 5,946,309.78 316,096.09 2.97 1,196.60 MWD+IFR-AK-CAZSC(3) 3,877.30 40.94 303.26 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1,255.11 MWD+IFR-AK-CAZSC(3) 3,971.83 40.95 30340 3,624.36 3,535.66 81049 -1,084.82 5,946,380.33 315,995.24 0.08 1,314.23 MWD+IFR-AK-CAZ-SG(3) 4,065.45 4097 3D3.86 3695.06 360636 844.47 -1,135.92 5,946,415.55 315,944.98 032 1,372.90 MWC+IFR-AK-CAZ-SC(3) 8/15/2018 5: 00 04P Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ER ConocoPhillips Definitive Survey ReportW Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05.aW.__.._ Project: Western North Slope TVD Reference: MT6-05 Actual @j 88.70usft (Actual D19) y Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual Q 88.70usft (Actual D79) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature P Design: MT6-05 Database: EDT 14 Alaska Production {: Survey t Map Map Vertical MD Inc AZI TVD TVDSS +N/-S+El-W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (=(1000 Section Survey Tool Name j (ft) (ft) (ft) i 4,159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946.451]6 315,893.96 1.20 1,432.81 MWD+IFR-AK-CAZ-SC(3) 4,254.03 43.41 305.40 3,834.89 3,746.19 915.89 -1,240.34 5,946,489.48 315,642.33 1.69 1,494.30 MWD+IFR-AK-CAZ-SC(3) 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -1,292+10 5,946.528.52 315,791.50 2.04 1,556.33 MWD+IFR-AK-CAZ-SG(3) 4,499.53 45.69 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571]8 315,736.38 0.68 1,624.33 MWD+IFR-AK-CAZ-SC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,693.25 MWD+IFR-AK-CAZ-SC(3) $ 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,996,657.02 315,626.12 0.23 1,759.33 MWD+IFR-AK-CAZ-SG(3) 41732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 0.75 1,823.28 MWD+IFR-AK-CAZ-SC(3) 4,824.17 45.60 304.58 4,235.60 4,146.90 1,154.17 -1,568.46 5,946,735.64 315,520.11 0.36 1,886.49 MWD+IFR-AK-CAZ-SC(3) 3 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,951.26 MWD+IFR-AK-CAZ-SC(3) ! 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813.73 315,410.16 0.33 2,015.66 MWD+IFR-AK-CAZ-SC (3) 5,106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1,735.77 5,946,852.98 315,355.62 0.42 2,080.14 MWD+IFR-AK-CAZ-SC (3) 5,201.23 45.65 304.35 4,499.23 4,410.53 1305.71 -1,791.40 5,946,892.59 315,300.93 0.22 2,144.96 MWD+IFR-AK-CAZ-SC(3) Y 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,209.76 MWD+IFR-AK-CAZ-SC (3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381,47 -1,903.39 5,946,971.00 315,190.62 0.28 2,274.51 MWD+IFR-AK-CAZ-SC(3) 5,483.33 45.32 304.10 4,697.00 4,606.30 1,418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2,337.67 MWD+IFR-AK-CAZ-SC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,402.27 MWD+1FR-AK-CAZ-SC (3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,466.51 MWD+IFR-AK-CAZ-SC (3) 5,766.67 45.12 306.17 4,896.71 4,808.01 1,533.09 -2,123.09 5,997,127.89 314,974.88 0.95 2,530.97 MWD+IFR-AK-CA7-SC (3) 5,861.26 45.08 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,595.95 MWD+IFR-AK-CAZ-SC (3) 5,953.99 45.13 307.58 5,028.93 4,940.23 1,61284 -2,229.14 5,947,210.19 314,870.81 0.43 2,659.85 MWD+IFR-AK-CAZ-SC(3) 6,048.44 45.4 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,724.99 MWD+IFR-AK-CAZ-SC (3) 1 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,789.86 MWD+IFR-AK-CAZ-SC (3) 6,235.05 45.6 307.01 5,227.45 5,138.75 1,734.21 -2,386.78 5,947,335.35 314,716.18 0.68 2,853.61 MWD+IFR-AK-CAZ-SC(3) 6,329,17 i 45.06 306.63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947,376.56 314,663.83 0.29 2,918.29 MWD+FR-AK-CAZ-SC (3) i 6,423.63 45.08 306.42 5,360.65 5,271.95 1,813.94 -2,493.85 5,897,417.65 314,611.08 0.16 2,983.12 MWD+IFR-AK-CAZ-SC (3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,653.46 -2,547.50 5,947,458.46 314,558.40 0.09 3,047.68 MWD+IFR-A)( CAZSC (3) j 6,612.19 45.05 306.15 5,493.76 5,405.06 1,693.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,112.47 MWD+IFR-AK-CAZSC(3) II 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947539.83 314,452.63 0.05 3,176.88 MWD+IFR-AK-CAZSC(3) 6,801.05 EEE. 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3,241.85 MWD+IFR-AK-CAZSC(3) 6,896.14 45.10 30510 5,694.24 5,605.54 2,011.13 -2,764.22 5.947 621 314,345.59 0.14 3,306.94 MWD+IFR-AK-CAZ-SC(3) 6,991.21 45.7 30568 5,761.36 5,672.66 2,050.40 -2,81890 5947,661.92 314,29189 0.03 3,3]197 MV ,IFR-AK-CAZ-SC(3) Annotation 8/15/2018 5'00:04PM Page 5 COMPASS 5000.14 Build 85 Conoco illips Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad -. Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: Well MT6-05 TVD Reference: MT6-05 Actual @ 88.70usft (Actual D79) MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) North Reference: True Survey Calculation Method; Minimum Curvature Database: EDT 14 Alaska Production 8/15/2018 5.00:04PM Page 6 R l% ES Annotation 9-5/8" x 12-1/4" COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easeing DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (-1100-) (=1100') Survey Tool Name (ft) (11) 7,85.78 45.08 305.19 5,828,15 5,739.45 2,089.22 -2,873.46 5,947,702.06 314,238.29 0.37 3,436.56 MVV)+IFR-AK-CAZ-SC(3) 7,179.83 45.10 305.01 5,894.55 5,805.85 2,127.52 -2,927.95 5,947,741.66 314,184.75 0.14 3,500.71 MM.IFR-AK-CAZ-SC(3) 7,273.52 45.05 304.86 5,960.71 5,872.01 2,165.51 -2,982.33 5,947,780.96 314,131.31 0.13 3,564.55 MWD+IFR-AK-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 -3,037.39 5,947,820.74 314,077.21 0.13 3,629.18 MWD+IFR-AK-CAZ-SC(3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 -3,091.64 5,947,860.21 314,023.90 0.15 3,693.07 MWD+1FR-AK-CAZ-SC(3) 7,555.32 45.01 304.78 6,159.73 6,071.03 2,28D.00 5,145.72 5,947,899.37 313,970.76 0.34 3,756.62 MWD+IFR-AK-CAZ-SC (3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 -3,20D.60 5.947,938.63 313,916.82 O19 3,820.73 MWD+IFR-AK-CAZ-SC (3) .7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 -3,254.29 5,947.977.43 313,854.06 0.65 3,883.77 MWD+IFR-AK-CA7-SC (3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3.WB.93 5,948,017.84 313,810.38 0.35 3,948.63 MWD+1FR-AK-CAZ-SC (3) 7,930.75 45.27 305.88 6,424.41 6,335.71 2,433.69 5,363.13 5,948,058.29 313,757.16 0.05 4,013.24 MWD+IFR-AK-CAZ-SC(3) 8,024.98 45.26 306.66 6,490.73 6,402.03 2,473.29 -3,417.09 5,948,099.19 313,704.18 0.59 4,078.06 MWD+IFR-AK-CAZSC(3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,513.32 .3,470.51 5,948,140.50 313,651.75 0.29 4,142.88 MWD+IFR-AKCAZSC(3) 8,212.40 45.10 306.82 6,622.70 6,534.00 2,553.17 -3,523.53 5,948,181.63 313,599.72 0.27 4,207.29 MWD+IFR-AKCAZSC(3) 8,306.99 45.05 306.73 6,689.49 6,600.79 2,593.27 -3,577.18 5,948,223.01 313,547.06 0.08 4,272.30 MWD+1FR-AKCAZSC(3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 5,630.98 5,948,263.96 313,494.25 0.50 4,337.06 MWD+IFR-AKCAZSC (3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 -3,684.69 5,948,304.31 313,441.50 0.05 4,401.30 MWD+IFR-AKCAZSC(3) 8,589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 -3,739.01 5,948,344.79 313,388.15 0.29 4,466.01 MWD+IFR-AKCAZSC(3) 8,685.37 45.05 305.58 6,956.81 6,868.11 2,750.49 -3,793.96 5,948,385.44 313,334.18 0.03 4,531.25 MWD+IFR.AKCAZ-SC(3) 8,779.66 45.06 306.70 7,023.42 6,934.72 2,789.84 -3,847.85 5,948,426.09 313,281.26 0.89 4,595.84 MWD+IFR-AKCAZ-SC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 -3,901.48 5,948,467.65 313,228.63 0.31 4,660.97 MWD+IFR.AK-CAZSC(3) 8,894.81 4504 307.55 7,104.76 7,016.06 2,838.87 5,912.96 5,948,476.68 313,217.37 1.49 4,675.01 MWD+IFR-AK-CAZ-SC (3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 5,923.22 5,998,489.85 313,207.30 0.78 4,687.64 MWD+IFR-AK-CAZ-SC(4) 8,968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 5,954.29 5,948,509.91 313,176.83 0.78 4,726.13 MWD+IFR-AK-CAZ-SC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 -3,999.04 5,948,546.27 313,132.96 0.68 4,781.78 MWD+IFR-AK-CAZ.SC(4) 9,143.80 45.26 30B.27 7,280.87 7,192.17 2,947.62 4,051.36 5,948,588.75 313,081.66 0.66 4,846.82 MWD+1FR-AK-CAZSC(4) 9,238.18 45.65 309.51 7,39].08 7,258.38 2,989.85 4,103.71 5,948,632.24 313,030.35 1.02 4,912.65 MWD+1FR-AKCAZSC(4) 9,332.26 48.44 311.65 7,411.19 7,322.49 3,034.66 4,155.97 5,948,678.30 312,979.20 3.40 4,980.43 MWD+IFR-AKCAZSC(4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4,210.09 5,948,727.23 312,926.26 3.28 5,051.56 MWD+IFR-AKCAZSC(4) 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4,266.03 5,948,777.27 312,871.52 2.72. 5,124.68 MWD+IFR-AKCAZ-SC(4) 9,61422 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5,948,829.46 312,814.26 2.03 5,201.03 MWD+IFR.AKCAZSC(4) 9706.62 59.30 312.69 7,631.91 7,543.21 3,233.78 -,38270 5,948,882.85 312,757.39 3.99 5,278.11 MWD+IFR-AK-CAZ-SC (4) 8/15/2018 5.00:04PM Page 6 R l% ES Annotation 9-5/8" x 12-1/4" COMPASS 5000.14 Build 85 ConocoPhillips UA<6R a ConoC Phr11 i'li I�UGNES p5 Definitive Survey Report Company: Cono=Phillips(Alaska) Inc. -WNS ProjeM: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MT6-05 Actual @J 88.70usft (Actual Of 9) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production .I f Annotation 7" x 8-3/4" TIP from MT6-05PB2 a/152018 5:00:04PM Page 7 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVD8S +W -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 9,801.05 61.09 315.59 7,678.85 7,590.16 3,290.84 -0,441.48 5,948,941.33 312,700.01 3.27 5,359.5D MWD+IFR-AK-CAZ-SC (4) 9,895.24 63.67 318.04 7,722.52 7,633.82 3,351.70 4.498.56 5,949,003.55 312,644.43 3.58 5,442.75 MWD+IFR-AK-CAZ-SC (4) 9,989.62 65.86 320.87 7,762.77 7,674.07 3,416.57 4,554.04 5,949,069.74 312,590.55 3.57 5,528.08 MWD+IFR-AK-CAZ-SC (4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 4,607.37 5,949,139.19 312,538.89 3.51 5,614.62 MWD+IFR-AK-CAZSC(4) 10,178.42 71.79 324.53 7,831.43 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,703.71 MWD+IFR-AK-CAZSC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 4,710.97 5,949,286.90 312,438.85 2.18 5,792.64 MW0+IFR-AK-CAZSC(4) 10,366.04 75.73 327.31 7,884.53 7,795.83 3,705.72 4,760.88 5,949,363.81 312,390.80 2.91 5,882.86 MWD+IFR-AK-CAZSC(4) 10,460.54 77.60 329.31 7,906.32 7,817.62 3,783.86 4.809.18 5,949,443.20 312,344.42 2.86 5,973.99 MWD+IFR-AK-CAZSC(4) 10,555.35 79.69 330.90 7,924.99 7,836.29 3,864.54 4,855.50 5,949,524.87 312,300.07 2.75 6,65.69 MWO+IFR-AK-CAZSC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4.900.44 5,949,607.76 312,257.14 1.90 6,157.48 MWD+IFR-AK-CAZ-SC(4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,249.71 MWD+IFR-AK-CAZ-SC(4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,986.88 5,949,776.06 312,174.76 1.14 6,340.89 MWD+IFR-AK-CAZ-SC(4) 10,933.50 82.85 332.88 7,977.79 7,889.09 4,195.72 -5,030.07 5,949,860.17 312,133.61 0.71 6,432.55 MWD+IFR-AK-CAZ-SC(4) 10,977.58 Kee 332.54 7,983.26 7,894.56 4,234.59 5,050.12 5,949,899.52 312,114.51 0.77 6,475.33 MWDAFR-AK-CAZ-SC (4) 11,028.48 82.91 332.15 7,989.56 7,900.86 4,279.33 5,073.56 5,949.944.81 312,092.16 0.77 6,524.80 MWD+IFR-AK-CAZSC(4) 11,106.00 82.89 332.81 7,999.14 7,910.44 4,347.55 -5,109.11 5,950,013.87 312,058.29 0.85 6,600.11 MWD-INC_ONLY(INC>10°)(5) 11,119.05 84.55 331.64 8,000.57 7,911.87 4,359,3 -5,115.13 5,950,025.50 312,052.54 14.71 6,612.81 MWD-INC_ONLY(INC>10°)(5) 11,212.00 84.82 325.68 8,009.19 7,920.49 4,438.13 5,163.11 5,950,105.73 312,006.50 6.61 6,704.41 MWD -INC -ONLY (INC>10') (5) 11,264.03 85.49 322.23 8,013.58 7,924.88 4,480.04 -5,193.61 5,950,148.36 311,977.03 6.73 6,756.16 MWD -INC -ONLY (INC>10') (S) 11,358.55 89.05 319.48 8,018.09 7,929.39 4,553.24 5,253.20 5,950,222.99 311,919.24 4.76 6,850.55 MWD -INC ONLY (INC>10°) (5) 11,453.90 91.38 316.71 8,017.73 7,929.03 4,624.19 5,316.87 5,950,295.46 311,857.31 3.80 6,945]8 MWD+IFR-AK-CAZSC(6) 11,549.18 91.92 317.12 8,014.99 7,926.29 4,693.75 5,381.93 5,950,366.57 311,793.97 0.71 7,040.81 MWD+IFR-AK-CAZ-SC(6) 11,644.55 92.44 320.77 8,011.36 7,922.66 4,765.60 5,444.51 5,950,439.92 311,733.16 3.86 7,136.05 MWD+IFR-AK-CAZ-SC (6) 11,739.78 93.27 324.15 8,006.61 7,917.91 4,841.01 5,502.45 5,950,516.70 311,677.06 3.65 7,231.11 MWD+IFR-AK-CAZ-SC (6) 11.834.89 91.02 326.98 8,003.05 7,914.35 4,919.38 -5,556.19 5,950,596.36 311,625.25 3.80 7,325.79 MWD+IFR-AK-CAZ-SG(6) 11,930.25 88.12 330.86 8,003.77 7,91507 5,001,3 -5,60540 5,950,679.17 311,576.04 5.08 7,420.14 MWD+IFR-AK-CAZSC(6) 12,025.83 89.93 335.47 8,005.39 7,916.69 5,086.27 -5,648.53 5,950,765.43 311,537.00 5.18 7,513.43 MWD+IFR-AK-CAZSC(6) 12,121.14 89.99 335.06 8,005.46 7,916.76 5,173.18 -5,687.65 5,95,853.26 311,500.00 0.62 7,605.47 MWD+IFR-AK-CAZSC(6) 12,216.12 88.90 338.34 8,006.38 7,917.68 5,260.73 -5,724.45 5,950,941.67 311,465.34 2.66 7,696.53 MWD+IFR-AK-CAZSC(6) 12.311.41 88.17 338.74 (3,008 82 7,920.12 5,349.39 -5,759.30 5,951,031.14 311,432.65 0.87 74787.21 MWD+IFR-AK-CAZSC(6) 12,406.40 88.42 33765 8.011.64 7,92294 5,437.54 -5,79457 5,951,120.12 31139954 1.18 7,87777 MWD+IFR-AK-CAZ-SC(6) Annotation 7" x 8-3/4" TIP from MT6-05PB2 a/152018 5:00:04PM Page 7 COMPASS 5000.14 Build 85 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MTB -05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey 8/1&1018 5:00:04PM Page 8 COMPASS 500014 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NAS +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) 1°) P) (usft) (ueft) (usft) (usft) (ft) (ft) (°1100') (fti 12,501.75 87.61 336.64 8,014.95 7,926.25 5,525.35 -5,831.58 5,951 208.79 311,364.67 1 36 7,969.17 MWD+IFR-AK-CAZ-SC (7) KOP OH ST 12,597.37 89.32 336.18 8,017.51 7,928.81 5,612.94 5,869.83 5,951,297.29 311,328.56 1.85 8,061.19 MWD+IFR-AK-CAZSC(7) 12,691.84 91.55 335.99 8,016.78 7,928.08 5,699.29 -5,908.12 5,951,384.54 311,292.38 2.38 8,152.27 MWD+IFR-AK-CAZSC(7) 12,787.01 93.64 339.73 8,012.30 7,923.60 6,787.33 5,94195 5,951 473.41 311,258.71 4.60 8,243.06 MWD+IFR-AK-CAZ-SC (7) 12,882.03 93.14 337.67 8,006.51 7,917.81 5,875.69 -5,978.40 5,951,562.57 311,226.42 2.29 8,333.29 MWD+IFR-AK-CAZ-SC (7) 12,977.39 93.40 340.58 8,001.07 7,912.37 5,964.63 5,012.32 5,951,652.31 311,194.67 3.06 8,423.61 MWD+IFR-AK-CAZSC(7) 13,073.68 93.46 343.07 7,995.31 2906.61 6,055.95 5,042.30 5,951,744.32 311,166.92 2.58 8,513.26 MWD+IFR-AK-CAZSC(7) 13,169.11 92.50 343.16 7,990.35 7,901.65 6,147.14 5,069.96 5,951,836.15 311,141.47 1.01 8,601.37 MWD+IFR-AK-CAZSC(7) 13,264.92 93.15 338.84 7,985.63 7,896.93 6,237.60 5,101.12 5,951,927.33 311,112.53 4.55 6691.10 MWD+IFR-AK-CAZ-SC(7) 13,360.50 93.02 336.30 7,980.48 7,891.78 6,325.81 -6,137.54 5,952,016.40 311,078.27 2.66 8,782.43 MWD+IFR-AK-CAZSC(7) 13,456.13 92.22 334.15 7,976.11 7,887.41 6,412.54 5,177.57 5,952,104.07 311,040.36 2.40 8,874.91 MWD+IFR-AK-CAZ-SC(7) 13,550.25 91.67 334.51 7,972.91 7,884.21 6,497.32 5,218.31 5,952,189.81 311,001.69 0.70 8,966.33 MWD+IFR-AK-CAZ-SC (7) 13,645.74 91.45 334.28 7,970.31 7,881.61 6,583.40 5,259.57 5,952,276.87 310,962.54 0.33 9,059.07 MWD+IFR-AK-CAZ-SC(7) 13,741.36 91.46 333.56 7,967.89 7,879.19 6,669.26 5,301.59 5,952,363.71 310,922.62 0.75 9,152.13 MWD+IFR-AK-CAZSC(7) 13,837.37 90.71 333.20 7,966.07 2877.37 6,755.06 5,344.60 5,952,450.54 310,881.70 0.87 9,245.79 MWD+IFR-AK-CAZSC(7) 13,932.40 90.50 332.78 7,965.07 7,876.37 6,839.74 5,387.75 5,952,536.22 3%840.62 0.49 9,338.64 MWD+IFR-AK-CAZSC(7) 14,027.09 95.45 333.08 7,960.15 7,871.45 6,923.91 5,430.78 5,952,621.41 310,799.66 5.24 9,431.03 MWD+IFR-AK-CAZ-SC(7) 14,122.22 94.96 331.89 7,951.52 7,862.62 7,007.93 -6,474.54 5,952,706.46 310,757.95 1.35 9,523.77 MWD+IFR-AK-CAZ-SC (7) 14,216.68 93.63 330.77 7,944.45 7,855.75 7,090.57 5,519.73 5,952,790.17 310,714.78 1.84 9,616.35 MWD+IFR-AK-CAZ-SC (7) 14,311.72 93.30 330.05 7,938.70 7,850.00 7,173.07 5,566.58 5,952,873.78 310,669.96 0.83 9,709.86 MWD+IFR-AK-CAZSC(7) 14,407.02 95.13 330.45 7,931.70 7,843.00 7,255.58 5,613]4 5,952,957.40 310,624.82 1.97 9,803.58 MWD+IFR-AK-CAZSC(7) 14,503.79 93.54 331.59 7,924.38 7,635.68 7,339.99 5,660.48 5,953,042.92 310,580.14 2.02 9,898.51 MWD+IFR-AK-CAZSC(7) 14,597.17 93.45 333.24 7,918.69 7,829.99 7,422.60 5,703.64 5,953,126.54 310,539.00 1.77 9,989.78 MWD+IFR-AK-CAZ-SC(7) 14,692.68 91.45 333.56 7,914.61 7,825.91 7,507.91 5,746.37 5,953,212.87 310,498.36 2.12 10,082.86 MWD+IFR-AK-CAZ-SC (7) 14,788.05 89.92 333.86 2913.47 7,824.77 7,593.41 5,788.60 5,953,299.35 310,458.22 1.63 10,175.76 MWD+IFR-AK-CAZ-SC (7) 14,883]4 87.80 333.46 7,915.37 7,826.67 7,679.14 5,831.05 5,953,386.09 310,417.87 2.25 10,269.01 MWD+IFR-AK-CAZSC (7) 14,978.03 87.90 332.09 2918.91 7,830.21 7,762.93 5,874.15 5,953,470.89 310,376.82 1.46 10,361.15 MWD+IFR-AK-CAZSC(7) 15,074.07 87.96 331.97 7,922.38 7,833.68 7,847.69 5,919.17 5,953,556.72 310,333.88 0.14 10,455.26 MWD+IFR-AK-CAZSC(7) 16,169.08 88.02 331.28 7,925.71 7,837.01 7,931.24 5,964.29 5,953,641.33 310,290.80 0.73 10,548.50 MWD+11FR-AK-CAZ-SC(7) 15,263.70 87.89 332.08 7,929.09 7,840.39 8,014.48 -2009.15 5,953,725.63 310,247.98 0.86 10,641.33 MWD+IFR-AK-CAZ-SC (7) 15,358.69 9009 32943 7,93077 7,84207 8.097.51 -7,055.64 5,953,809.76 310,2D3.52 3.62 10.735.03 MV +1FR-AK-CAZ-SC(7) 8/1&1018 5:00:04PM Page 8 COMPASS 500014 Build 85 survey ConocoPhillips a f ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-O5 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) + Well: MT6-05 North Reference: True 1 Wellbore: MT6-05 Survey Calculation Method; Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production survey Annotation Projection to TO - 4-1/2" x 6" aH5@O1B 5.00.04PM Page 9 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Eastin DLS Section (usft) (°) r) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft)9 (ft) 15,454.82 89.92 330.25 7,930.76 7,842.06 8,180.45 -7,103.84 5,953,893.85 310,157.35 0.87 10,829.74 MWD+IFR-AK-CAZ-SC(7) 15,550.30 90.05 331.70 7,930.78 7,842.08 8,263.94 -7,150.16 5,953,978.43 310,113.07 1.52 10,923.69 MWD+IFR-AK-CAZ-SC (7) 15,645.82 89.98 332.46 7,930.76 7,842.06 8,348.34 -7,194.89 5,954,063.89 310,070.41 0.80 11,017.34 MWD+IFR-AK-CAZSC(7) 15,740.85 9005 333.92 7,930.73 7,842.03 8,433.15 -7,237.75 5,954,149.71 310,029.63 1.54 11,110.12 MWD+IFR-AK-CAZSC(7) 15,836.28 90.82 335.14 7,930.01 7841.31 8,519.30 -7,278.79 5,954,236.83 309,990.70 1.51 11,202.78 MWD+IFR-AK-CAZSC(7) 15,931.32 95.94 335.38 7,924.41 7,835.71 8,605.44 -7,318.48 5,954,323.90 309,953.11 5.39 11,294.58 MWD+IFR-AK-CAZSC(7) 16,026.40 95.54 335.00 7,914.90 7,826.20 8,691.31 4,358.18 5,954,410.70 309,915.52 0.58 11,366.18 MWD+IFR.AK-CAZ-SC(7) 16,122.04 92.86 334.50 7,907.89 7,819.19 8,77T57 -7,398.86 5,954,497.92 309,876.94 2.85 11,478.71 MWD+IFR-AK-0AZ-SC(7) 16,217.43 93.07 334.33 7,902.96 7,814.26 8,863.49 -7,440.00 5,954,584.81 309,837.90 0.28 11,571.26 MWD+11FR-AK-CAZ-SC (7) 16,312.20 92.03 333.38 7,898.74 7,810.04 8,948.48 .7,481.72 5,954,670.78 309,798.26 1.49 11,663.45 MWD+IFR-AK-CAZSC (7) 16,407.71 89.92 332.05 7,897.12 7,808.42 9,033.34 -7,525.49 5,954,756.68 309,756.57 2.61 11,756.85 MWD+IFR-AK-CAZSC(7) 16,502.31 89.33 332.14 7,89T74 7,809.04 9,116.94 -7,569.76 5,954,841.32 309,714.34 0.63 11,849.58 MWD+IFR.AK-CAZSC(7) 16,598.23 89.18 332.24 7,898.98 7,810.28 9,201.78 -7,614.51 5,954,927.21 309,671.67 0.19 11,943.58 MWD+IFR-AK-CAZSC(7) 16,693.10 90.20 333.00 7,899.50 7,810.80 9,286.02 -7,658.14 5,955,012.48 309,630.10 1.34 12,035.40 MM+IFR-AK-CAZSC (7) 16,768.77 90.57 332.18 7,898.85 7,810.15 9,370.94 -7,702.18 5,955,098.45 309,586.14 0.94 12,130.02 MWD+IFR.AK-CAZ-SC(7) 16,884.82 91.15 331.27 7,897.41 7,806.71 9,455.52 -7,747.67 5,955,184.10 309,544.72 1.12 12,224.29 MWD+IFR-AK-CAZ-SC (7) 16,980.71 91.18 332.05 7,895.46 7,806.76 9,539.90 -7,793.18 5,955.269.55 309,501.27 0.81 12,318.41 MWD+IFR-AK-CA7-SC (7) 17,075.73 91.21 332.68 7,893.48 7,804.78 9,624.06 -7,837.24 5,955,354.76 30$459.27 0.66 12,411.45 MWD+IFR-AK-CAZ-SC (7) 17,171.05 90.68 333.15 7,891.91 7,803.21 9,706.92 -7,880.64 5,955,440.63 309,417.95 0.74 12,504.60 MWD+IFR-AK-CAZSC(7) 17,266.28 91.89 332.62 7,889.77 7,801.07 9,793.66 -7,924.03 5,956,526.40 309,376.63 1.39 12,597.67 MWD+IFR-AK-CAZSC(7) 17,362.98 91.86 332.60 7,886.61 7,797.91 9,879.47 -7,968.49 5,955,613.26 309,334.27 0.04 12,692.24 MWD+IFR-AK-CAZSC(7) 17,39100 91.66 33260 7,685.70 7,797.00 9,904.33 -7,981.38 5,955,638.43 309,32199 000 12719.64 PROJECTED to TO Annotation Projection to TO - 4-1/2" x 6" aH5@O1B 5.00.04PM Page 9 COMPASS 5000.14 Build 85 BA ER011 i-IGHES a G£ company To Date: November 28, 2018 Alfiy Bell AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 From: 21 8045 -- -71 Tz- Letter of Transmittal G-" Irl o,' Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94' Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): MT6-OSPB1 MT6-05PB2 MT6-05 MT6-05Ll REC EI\ / ED Nov 2 9 2018 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BHGE.com w P v SMER so Date: �ESOctober 11, 2018 G To: Meredith Guhl AOGCC 333 West 7' Ave, Suite 100 Anchorage, Alaska 99501 From: 21 8045 29792 Letter of Transmittal Michael Soper/Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 1H -21A 1H-21AL1 1H-21AL2 IH-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 MT6-05PB1 MT6-05PB2 MT6-05 MT6-05L1 MT6-08PB1 MT6-O8 RECEIVED OCT 12 2018 AOGCC Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsing_h@BHGE.com CM ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05PB1 50-103-20771-70 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 2 180 45 BAT(ER UGHES a GE company �. ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhiIli ps(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88 70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska 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) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-05 Well Position +N/ -S 0.00 usft Northing: 5, 945,543.79usft Latitude: +E/ -W 0.00 usft Easting: 317,059.98usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: O.00usft Ground Level: Wellbore MT6-05PB1 Magnetics Model Name Sample Date Declination (1) Dip Angle (') BGGM2017 5/20/2018 16.50 80.72 Design MT6-05PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36 50 Vertical Section: Depth From (TVD) (usft) 0.00 +Nl-S +E/ -W (usft) (usft) 0.00 0.00 Direction (1) 320.84 HAIER UGNES 70° 15'21964 N 151' 28'42.930 W 37.20 usft Field Strength (nT) 57,422 8%5/2018 4'58: 53PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips9%ES Conoco IPS Definitive Survey Report Company: ConocoPhllllps(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Local Co-ordinate Reference: Well MTB -05 TVD Reference: MT6-05 Actual @ 88.70usfl (Actual D19) MD Reference: MT6-05 Actual @ 88.70usft (Actual D79) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Survey Program Survey Date End Date 5/13/2018 5/13/2018 5/15/2018 UNDEFINED 5/21/2018 From To GYD-CT-DMS(1) 6/4/2018 GYD-CT-DMS(1) -0.62 MWD-IFR-AK-CAZ-SC (2) -0.32 MWD+IFR-AK-CAZ-SC (2) (usft) (usft) Survey (Wellbore) MWD-IFR-AK-CAZ-SC (2) 13.43 Tool Name 23.17 Description 35.11 60.26 263.26 GYD Gyro DMS 16" (MT6-05PB7) MWO+IFR-AK-CAZ-SC (2) GYD-CT-DMS MWD+IFR-AK-CAZSC(2) Gyrodata cont.drillpipe m/s 296.26 1,957.96 BHGE MWD+IFR+MSA 16"(MT6-05PB1 MWD+IFR-AKCAZ-SC(2) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4" (MT6-05 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,968.80 11,198.88 BHGE MWD+IFR+MSA 6x8-3/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,268.35 11,935.87 BHGE MWD+IFR+MSA6"(MT6-05PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Map Map MD Inc Azi TVD TVDSS +NIS +EFW Northing Northing sti Fasting DLS (usft) C) V) (usft) (usft) (usft) (usft) (°1100') 36.50 0.00 0.00 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 0.00 60.26 0.33 231.64 60.26 -28.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 161.76 0.36 194.38 161.76 73.06 -0.53 -0.36 5,945,543.27 317,059.61 0.22 263.26 0.56 211.72 263.25 174.55 -1.26 -0.70 5,945,542.54 317,059.25 0.24 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96 1.31 390.15 1.24 252.95 390.13 301.43 -2.46 -2.50 5,945,541.40 317,057.42 0.64 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 577.56 3.84 299.00 577.36 488.66 0.13 -9.59 5,945,54446 317,050.40 1.76 672.51 5.46 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 766.06 7.00 304.80 764.99 676.29 9.88 .24.57 5,945,554.26 317,035.66 1.63 860.61 8.03 306.69 858.72 770.02 17.11 -34.60 5,945,561.73 317,025.81 1.12 955.24 8.96 307.34 952.31 863.61 25.53 45.76 5,995,570.42 317,014.86 0.99 1,048.71 10.08 306.87 1,044.50 955.80 35.08 57.91 5,945,580.26 317,002.94 1.23 1143.88 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 1,238.25 12.95 310.96 1,230.19 1,14149 59.31 -87.07 5,945,605.19 316,974.39 1.50 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945.620.06 316,957.95 1.25 1427.45 14.70 308.04 1,413.78 1,325.08 88.66 -122.08 5,945,635.38 376,940.10 0.89 1521.38 15.39 305.44 1,504.49 1,415.79 103.23 -141.62 5,945,650.42 316,920.92 1.03 161689 14.91 304.96 1,596.68 1507.98 117.62 -162.02 5,945,665.30 316,900.88 0.52 Survey Survey Start Date End Date 5/13/2018 5/13/2018 5/15/2018 UNDEFINED 5/21/2018 GYD-CT-DMS(1) 6/4/2018 GYD-CT-DMS(1) 6/4/2018 GYD-CT-DMS(1) ca Section Survey Tool Name Annotation Iftl 0.00 UNDEFINED 0.00 GYD-CT-DMS(1) -0.18 GYD-CT-DMS(1) -0.54 GYD-CT-DMS(1) -0.62 MWD-IFR-AK-CAZ-SC (2) -0.32 MWD+IFR-AK-CAZ-SC (2) 1.64 MWD+IFR-AK-CA7SC(2) 6.16 MWD-IFR-AK-CAZ-SC (2) 13.43 MWD+IFR-AKCAZSC(2) 23.17 MWD+IFR-AKCAZSC(2) 35.11 MWD+IFR-AK-CAZ-SC(2) 48.69 MWD+IFR-AK-CAZ-SC (2) 6377 MWO+IFR-AK-CAZ-SC (2) 81.27 MWD+IFR-AK-CAZSC(2) 100.97 MWD+IFR-AKCAZSC(2) 122.79 MWD-IFR-AK-CAZ-SC (2) 145.84 MWD+IFR-AKCAZ-SC(2) 169.47 MWD+IFR-AK-CAZ-SC (2) 193.51 MWD+IFR-AK-CAZ-SC(2) 81152018 4:58:53PM Page 3 COMPASS 5000.14 Build 85 ✓ ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database Well MT6-05 MT6-05 Actual @ 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production SAKER 9E j i -. Survey.._._..____"___ Map Map Vertical MD Inc AzI 1VD TVDSS +N/S +E/-W DLS (usft) (°) C) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 216.93 MWD+IFR-AK-CAZ-SC (2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 242.08 MWD+IFR-AK-CAZSC(2) 1,899.91 18.01 307.58 1,868.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.23 MWD+IFR-AK-CAZSC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 287.10 MWD+IFR-AK-CAZSC(2) 1 2,014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,810.51 0.83 304.95 MWD+IFR-AK-CAZSC (3) 13-3/8" X 16" 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 316.80 MWD+IFR-AK-CAZSC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 329.73 MWD+IFR-AK-CAZSC (3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 -3()1.15 5,945,774.29 316764.37 2.55 363.28 MWD+IFR-AK-CAZSC(3) I 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 -331.10 5,945,798.93 316,735.00 2.78 400.75 MWD+IFR-AK-CAZ-8C(3) t 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 -363.43 5,945,825.26 316,703.30 1.60 440.98 MWD+IFR-AK-CAZ-SC (3) 2,467.33 27.46 306]8 2,391.02 2,302.32 299.60 -397.30 5,945,&52.94 316,670.10 0.85 483.20 MWD+1FR-AK-CAZ-SC(3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 432.25 5,945,880.75 316,635.82 2.80 526.18 MWD+IFR-AK-CAZSC(3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 -469.44 5,945,909.21 316,599.32 1.14 571.04 MWD+FR-AK-CAZ-SC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 508.33 5,945,939.34 316,561.15 1.05 618.24 MWD+1FR-AK-CAZ-SC (3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 -548.00 5,945,970.76 316,522.23 0.56 666.92 MWD+1FR-AK-CAZ-SC (3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 587.97 5,946,002.74 316,483.03 0.12 716.21 MWD+IFR-AK-CAZ-SC (3) 3,028.87 32.99 308.00 2,871.15 2,782.45 476.32 828.35 5,946,035.20 316,443.43 0.73 766.12 MWD+IFR-AK-CAZ-SC(3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 869.28 5,946,067.97 316,403.28 0.64 816.63 MWD+IFR-AK-CAZ-SC(3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946,101.09 316,362.09 1.33 868.03 MWD+1FR-AK-CAZ-SC (3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 920.90 MWD+IFR-AK-CAZ-SC (3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946,169.49 316,276.14 0.79 974.75 MWD+IFR-AK-CAZ-SC(3) 3,500.89 36.47 306.40 3,257.86 3,169.16 640.06 843.65 5,946,204.11 316,232.18 0.59 1,029.05 MWD+IFR-AK-CAZ-SC(3) 3,594.37 37.D6 306.99 3,332.75 3,244.05 673.49 BB8.51 5,946,238.62 316,188.14 0.74 1,083.30 MWD+IFR-AK-CAZ-SC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 -934.17 5,946,274.11 316,143.34 0.65 1,138.80 10WD+1FR-AK-CAZ-SC(3) I 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 -982.28 5,946,309.78 316,096.09 2.97 1,195.94 MWD+1FR-AK-CAZ-SC (3) 3,87730 40.94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1,254.41 MWD+IFR-AK-CAZ-SC(3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084.82 5,946,380.33 315,995.24 0.08 1,313.49 MWD+IFR-AK-CAZSC(3) 4,065.45 40.97 3D3.86 3,695.06 3,606.36 844.47 -1,135.92 5,946,415.55 315,944.98 0.32 1,372.11 10WD+1FR-AK-CAZ-SC(3) 4,159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,451.76 315,893.96 1.20 1,431.99 MWD+IFR-AK-CAZ-SC (3) 4,254.03 43.41 305.40 3,834.89 3,746.19 915.89 -1240.34 5,946.489.48 315,842.33 1.69 1,493.43 MWD+IFR-AK-CAZ-SC(3) 4,345.97 44.99 306.85 3,900.8D 3.612.10 953.69 -1,292.10 5,946528.52 315,]91.50 2.04 1,55542 MWD+IFR-AK-CAZ-SC(3) 8/15/2018 4'58: 53PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BAER �c�1Es ConocoPhIIIIpS Definitive Survey Report t4MIM Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MTS -05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTS -05 Actual @ 88.70usft (Actual D19) Well: MTS -05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey x/15/2018 4:58:53PM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS -NIS +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) ("1100') Survey Tool Name Annotation (ft) (ft) (ft) 4,444.53 45.64 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571.78 315,736.38 0.68 162338 MWD+1FR-AK-CAZ-SC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,692.27 MWD+IFR-AK-CAZ-SC(3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,758.31 MWD+IFR-AK-CAZ-SC (3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 0.75 1,822.22 MWD+IFR-AK-CAZ-SC(3) 4,824.17 45.60 304.58 4,235.60 4.146.90 1,154.17 -1,568.46 5,946,735.64 $15,520.11 0.35 1,885.39 MWD+IFR.AK-CAZ-SC (3) 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,950.12 MWD+IFR-AK-CAZSC(3) 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813.73 315,410.16 0.33 2,014.47 MWD+IFR-AK-CAZSC(3) 5,106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1,735.77 5,946,852.98 315,355.62 0.42 2,078.91 MWD+IFR-AK-CAZSC(3) 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,946,892.54 315,300.93 0.22. 2,143.68 MWD+IFR-AK-CAZSC(3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,34371 -1,847.30 5,946,931.88 315,245.97 0.23 2,208.44 MWD+IFR-AK-CAZSC(3) 5,390.61 45.36 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.28 2,273.14 MWD+IFR-AK-CAZSC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2,335.27 MWD+IFR-AK-CAZSC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,400.82 MWD+1FR-AK-CAZ-SC(3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,465.02 MWD+IFR-AK-CAZ-SC(3) 5,766.67 45.12 306.17 4,896.71 4,808.01 1,533.09 -2,123.07 5,997,127.89 314,974.88 0.95 2,529.44 MWD+IFR-AK-CAZ-SC (3) 5,861.26 45.08 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947.169.13 314,922.08 0.64 2,594.36 MWD+IFR-AK-CAZ-SC (3) 5,953.99 45.13 307.58 5.28.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,658.25 MWD+IFR-AK-CAZ-SC(3) 6,048.44 4504 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,723.35 MWD+IFR-AK-CAZSC(3) 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,788.19 MWD+IFR-AK-CAZSC(3) 6,235.05 45.06 307.01 5,227.45 5,138.75 1,734.21 -2,386.78 5,947,335.35 314,716.18 0.68 2,851.91 MWD+IFR-AK-CAZSC(3) 6,263.16 45.06 306.90 5,247.31 5,158.61 1,746.18 -2,402.68 5,947,347.70 314,700.57 0.29 2,871.22 MWD+IFR-AK-CAZSC(3) GMT1-B7 T2 6,329.17 45.05 306.63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947,376.56 314,663.83 0.29 2,916.54 MWD+1FR-AK-CAZSC(3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1,813.94 -2,493.85 5,947,417.65 314,611.08 0.16 2,981.34 MWD+IFR-AK-CAZSC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.6 -2,547.50 5,947,458.46 314,558.40 0.09 3,045.86 MWD+IFR-AK-CAZSC(3) 6,612.19 45.05 306.15 5,493.76 5,405.06 1,893.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,110.61 MWD+IFR-AK-CAZ-SG(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3,174.98 MWD+IFR-AK-CAZ-SC (3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3,239.92 MWD+IFR-AK-CAZSC(3) 6,895.14 45.10 305.70 5,694.24 5,605.54 2,011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,304.97 MWD+IFR-AK-CAZ-SC(3) 6,991.21 45.07 305.68 5,761.36 5,672.66 2,050.40 -2,818.90 5,947,661.92 314,291.89 0.03 3,369.96 MWD+1FR-AK-CAZSC(3) 7,08578 45.08 305.19 5,828.15 5,739.45 2,089.22 -2,873.46 5,947,702.06 314,238.29 0.37 3,434.51 MWD+IFR-AK-CAZSC(3) 7,179.83 45.10 305.01 5,894.55 5,80585 2,12752 -2,92795 5,947,74166 314,184.75 0.14 3,49862 MWD+IFR-AK-CAZ-8C(3) x/15/2018 4:58:53PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report W ! "mss Company: Project: Site: Well: Wellbore: Design: ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMTt Lookout Pad MT6-05 MT6-05 MT6-05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MT6-05 Actual @ 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production Survey �- Map Map . Vertical MD Inc Azi ND NDSS +N/S +E/ -W Northing Easting OLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 7,273.52 45.05 304.86 5,960.71 5,872.01 2,165.51 .2,982.33 5,947,78096 314,131.31 CA3 3,562.41 MWD+IFR-AK-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 -3,037.39 5,947,820.74 314,077.21 0.13 3,627.00 MWD+IFR-AK-CAZSC (3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 -3,091.64 5,947,860.21 314,023.90 0.15 3,690.85 MWD+IFR-AK-CAZSC(3) 7,555.32 45.01 304.78 6,159.73 6,071.03 2,280.00 -3,145.72 5,947,899.37 313,970.76 0.34 3,754.36 MWD+IFR-AK-CAZSC(3) j 7,649.62 45.05 304.53 6,226.37 6,13].6] 2,317.94 -3,200.60 5,947,938.63 373,916.82 0.19 3,818.43 MWD+IFR-AK-CAZ-SC (3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 -3,254.29 5,947,977.43 313,864.0(1 0.65 3,881.43 MWD+IFR-AK-CAZ-SC (3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,948,017.84 313,810.38 0.35 3,946.25 MWD+IFR-AK-CAZ-SC (3) 7,930.75 45.27 305.88 6,424.41 6,335]1 2,433.69 -3,363.13 5,948,058.29 313,757.16 0.05 4,010.82 MWD+IFR-AK-CAZ-SC (3) 8,024.98 45.26 306.66 6,490.73 6,402.03 2,473.29 -3,417.09 5,948,099.19 313,704.16 0.59 4,075.61 MWD+IFR-AK-CAZ-SC (3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,513.32 .3,470.51 5,948,140.50 313,651 ]5 0.29 4,140.38 MWD+IFR-AK-CAZ-SC (3) 8,212.40 45.10 306.82 6,622.70 6,534.00 2,553.17 -3,523.53 5,948,181.63 313,599.72 0.27 4,204.76 MWD+1FR-AK-CAZ-SC (3) 8,306.99 45.06 306.73 6,689.49 6,600.79 2,593.27 .3,577.18 5,948,223.01 313,547.06 0.08 4,269.73 MWD+IFR-AK-CAZSC(3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 -3,630.98 5,948,263.96 313,494.25 0.50 4,334.45 MWD+IFR-AK-CAZSC(3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 -3,684.69 5,948,304.31 313,441.50 0.05 4,398.66 MWD+IFR-AK-CAZSC(3) i 8,589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 -3,739.01 5.948.344.79 313,388.15 0.29 4,463.33 MWD+IFR-AK-CAZSC(3) 8,685.37 45.05 305.58 6,956.81 6,868.11 2,750.49 .3,793.96 5,948,385.44 313,334.18 0.03 4,528.53 MWD+IFR-AK-CAZSC (3) 8,779.66 45.06 306.70 7,023.42 6,934.72 2,789.84 -3,847.86 5,948,426.09 313,281.26 0.84 4,593.08 MWD+1FR-AK-CAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 -3,901.48 5,948,467.65 313,228.63 0.31 4.658.17 MWD+IFR-AKCAZSC(3) 8,894.81 45.04 307.55 7,104.76 7,016.06 2,838.87 -3,912.96 5,948,476.68 313,217.37 1.49 4,672.21 MWD+IFR-AKCAZSC(3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 43,923.22 5,94$484.85 313,207.30 0.78 4,684.83 MWD+IFR-AKCAZSC(4) 9-5/8"X12-1/4" 8,968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 -3,954.29 5,948,509.91 313,176.83 0.78 4,723.30 MWD+IFR-AKCAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 -3,999.04 5,948,546.27 313,132.96 0.68 4,778.92 MWD+IFR-AKCAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,94].62 4,051.36 5,948,588.75 313,081.65 0.66 4,843.92 MWD+IFR-AKCAZ-SC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,989.85 4.103.71 5,948,632.24 313,030.35 1.02 4,909.73 MWD+IFR-AKCAZ-SC(4) 9,332.26 48.44 311.66 7,411.19 7,322.49 3,034.66 4.155.97 5,948,678.30 312,979.20 3.40 4,977.48 MWD+IFR-AK-CAZ-SC (4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4.210.09 5,948,727.23 312,926.26 3.28 5,048.58 MW0+IFR-AK-CAZ-8C(4) I� 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4,266.03 5,948,777.27 312,871.52 2.72 5,121.67 MWD+IFR-AKCAZSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5,948,829.46 312,814.26 2.03 5,198.00 MWD+IFR-AKCAZSC(4) 9,706.62 59.30 312.69 7,631.91 7,543.21 3,233.78 4,382.70 5,948,882.85 312,757.39 3.99 5,275.05 MWD+IFR-AK-CAZSC(4) 9801.05 61.09 315.59 7,678.86 7,59046 3,290.84 4,441.48 5,948,941.33 312,700.01 3.27 5,356.41 MW AFF-AK-CAZSC(4) 9.895.24 63.67 318.04 7,722.52 7,633.82 3,351.70 -0,498.56 5,949,00355 312,644.43 3.58 543965 MWD+IFR-AK-CAZ-SC(4) 611572018 4'58:53PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips ER �i �EYs ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS� Local Co-ordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 8B.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True r Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production ( TVDSS -NAS +El -W Northing Easting Survey I Map Map Vertical MD Inc Azi TVD TVDSS -NAS +El -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 4 9,989.62 65.66 320.87 7,762.77 7,674.07 3,416.57 -0,554.04 5,949,06974 312,590.55 3.57 5,524.98 MWD+IFR-AK-CAZ-SC(4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 4,607.37 5,949,139.19 312,535.89 3.51 5,611.52 MWD+IFR-AK-CAZ-SC(4) 10,178.42 71.79 324.53 7,831.43 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,700.62 MWD+IFR-AK-CAZ-SC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,63D.00 4,710.97 5,949,286.90 312,438.85 2.18 5,789.57 MWD+IFR-AK-CAZ-SC (4) I 10,348.68 75.29 327.05 7,880.18 7,791.48 3,691.60 4751.78 5,949,349.48 312,399.56 2.91 5,863.10 MWD+IFR-AK-CAZ-SC (4) GMT1-B1 T1 (copy) 10,366.04 75.73 327.31 7,884.53 7,795.83 3,705.72 -0,76(3.88 5,949,363.81 312,390.80 2.91 5,879.80 MWD+IFR-AK-CAZ-SC (4) 10,460.54 77.60 329.31 7,906.32 7,817.62 3,783.96 4,809.18 5,949,443.20 312,344.42 2.96 5,970.97 MWD+IFR-AK-CAZ-SC (4) t 10,555.35 79.69 330.90 7,924.99 7,836.29 3,864.54 4,855.50 5,949,524.87 312,300.07 2.75 6,062.70 MWD+IFR-AK-CA7-SC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,607.76 312,257.14 1.90 6,154.53 MWD+IFR-AK-CAZSC(4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,246.80 MWD+IFR-AK-CAZSC(4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,986.88 5,949,776.06 312,174.76 1.14 6,338.03 MWD+IFR-AK-CAZSC(4) 10,933.50 82.85 332.88 7,977.79 7,889.09 4,195.72 -5,030.07 5,949,860.17 312,133.61 0.71 6,429.73 MWD+IFR-AK-CAZSC(4) 10,977.58 82.68 332.54 7,983.26 7,894.56 4,234.59 -5,050.12 5,949,899.52 312,114.51 0.77 6,472.53 MWD+IFR-AK-CAZSC(4) 7"x8-3/4" 11,028.48 82.91 332.15 7,989.56 7,900.86 4,279.33 -5,073.56 5,949,944.81 312,092.16 0.77 6,522.02 MWD+1FR-AK-CAZSC (4) 11,123.21 82.88 332.95 8,001.28 7,912.58 4,362.75 -5,116.90 5,950,029.25 312,050.87 0.84 6,614.07 MWD+IFR-AK-CAZSC(4) e 11,198.88 82.88 332.19 8,010.66 7,921.96 4,429.39 5,151.49 5,950,096.71 312,017.91 1.00 6,687.59 MWD+IFR-AK-CAZ-SC(4) 11,268.35 83.00 331.32 8,019.20 7,930.50 4,490.12 5,184.11 5,950,158.21 311,986.77 1.25 6,755.28 MWD+IFR-AK-CAZ-SC(5) 11,363.64 82.97 331.64 8,030.83 7,942.13 4,573.22 -5,229.27 5,950,242.38 311,943.65 0.33 6,648.23 MWD+IFR-AK-CAZ-SC(5) e 11,459.23 82.96 332.49 8,042.54 7,953.84 4,657.D4 5,273.71 5,950,327.25 311,90L25 0.88 6,941.29 MWD+IFR-AK-CAZ-SC (5) 11,554.02 83.37 332.80 8,053.82 7,965.12 4,740.63 5,316.96 5,950,411.85 311,860.06 0.54 7,033.41 MWD+IFR-AK-CAZ-SC (5) 11,648.96 87.24 333.40 8,061.59 7,972.89 4,825.00 5,35916 5,950,497.23 311,819.32 4.12 7,125.86 MWD+1FR-AK-CAZ-SC (5) 11,744.77 92.76 337.30 8,061.59 7,972.89 4,912.D3 -5,399.70 5,950,585.20 311,781.51 7.05 7,218.56 NIM+IFR-AK-CAZ-SC (5) 11,840.18 93.46 335.49 8,056.42 7,967.72 4,999.32 -5,437.84 5,950,673.39 311,745.50 2.03 7,310.33 MWD+1FR-AK-CAZSC (5) 11,935.87 93.52 334.32 8,050.59 7,961.89 5,085.82 -5,478.35 5,950,760.84 311,707.10 1.22 7,402.98 MWD+IFR-AK-CAZSC(5) 12,037.00 93.52 334.32 8,044.38 7,955.68 5,176.78 -5,522.09 5,950852.84 311,665.59 0.00 7,501.14 PROJECTEDto TD 41/2 x6" 87152018 4:58:53PM Page 7 COMPASS 5000.14 Build 85 ER ( I Date: �t I HES BAT GE company To Aihy Bell AOGCC 333 West 711 Ave, Suite 100 Anchorage, Alaska 99501 November 28, 2018 From: 21 8045 Letter of Transmit al 112e-vzc� Michael Soper / Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): MT6-05PB1 MT6-05PB2 MT6-OS MT6-05RECEIVED L1 NOV 19 1018 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BHGE.com 218045 29793 Letter of Transmittal BER ' Date: --- -- AT( October 11, 2018 a GF company To: Meredith Guhl AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Michael Soper/Yosha Ragbirsingh Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): KUPARUK RIVER UNIT 3H -31A 3H-31AL1 1H -21A 1H-21AL1 1H-21AL2 1H-21AL2-01 (14) Total prints GREATER MOOSES TOOTH UNIT MT6-03PH MT6-03 RECEIVED MT6-05PB1 M76-05PB2 OCT 12 2018 MT6-05 AOGCC MT6-05L1 MT6-08PB1 MT6-08 Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com Z5 �q5 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05PB2 50-103-20771-71 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 21 8045 BA ER F�UGHES a GE company ConocoPhillips Company: Conoco Phillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum. Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well MT6-05 ConocoPhillips Definitive Survey Report Local Coordinate Reference: Well MT6-05 TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) MD Reference: MTS -05 Actual @ 88.70usft (Actual D19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position +NIS 0.00 usft Northing: Audit Notes: +El -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MT6-05PB2 Magnetics Model Name Sample Date Phase: ACTUAL Depth From (TVD) (usft) 0.00 5/20/2018 Mean Sea Level Using geodetic scale factor 5,945,543.79 usft 317,059.98 usft 0.00usft Declination (1) 16.50 Tie On Depth: 11,028.48 +NIS (usft) 0.00 +E/ -W (usft) 0.00 Latitude: Longitude; Ground Level: Dip Angle V) 80,72 Direction (°I 316.54 BAER u 'ME 70° 15'22.964 N 151' 28'42.930 W 37.20 usft Field Strength (nT) 57,422 8/15/2018 4: 5936PM Page 2 COMPASS 500014 Build 85 BGGM2017 Design MT6-05PB2 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) (usft) 0.00 5/20/2018 Mean Sea Level Using geodetic scale factor 5,945,543.79 usft 317,059.98 usft 0.00usft Declination (1) 16.50 Tie On Depth: 11,028.48 +NIS (usft) 0.00 +E/ -W (usft) 0.00 Latitude: Longitude; Ground Level: Dip Angle V) 80,72 Direction (°I 316.54 BAER u 'ME 70° 15'22.964 N 151' 28'42.930 W 37.20 usft Field Strength (nT) 57,422 8/15/2018 4: 5936PM Page 2 COMPASS 500014 Build 85 ConocoPhillips BA ER 0 ConocoPhillips Definitive Survey Report U°GFH `. Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MTB -05 Project Western North Slope ND Reference: MT6-05 Actual @ 88.70usft (Actual D19) { Site: GMT1 Lookout Pad MD Reference: MTS -05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellborn: MT6-05 Inc Survey Calculation Method: Minimum Curvature NDSS Design: MT6-05 Northing Database: EDT 14 Alaska Production Section Survey Program (% Date (usft) (usft) (usft) From To Survey Tool Name Annotation Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date 60.26 263.26 GYD Gyro DMS 16" (MT6-05PB1) GYD-CT-DMS Gyrodata cont.drillpipe m/s 5/13/2018 296.26 1,957.96 BHGE MWD+IFR+MSA 15" (MT6-05PB1 MWD+IFR-AK-CAZ-SC MWD+IFR. AK CAZ SCC 5/15/2018 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4"(MT6-05 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/21/2018 8,968.80 11,028.46 BHGE MWD+IFR+MSA 6x8-3/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/4/2018 11,106.00 11,358.55 BHGE MWD INC 6" (MT6-05PB2) MWD -INC -ONLY (INC>70°) MWD -INC -ONLY -FILLER ( INC>10°) 6/22/2018 11,453.90 13,740.32 BHGE MWD+IFR+MSA6"(MT6-05PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/22/2018 SNNey End Data 5/13/2018 Survey, i Map Map Vertical MD Inc Ami ND NDSS +N/ -S +EI -W Northing Fasting DLS Section (ue@) (% (°) (usft) (usft) (usft) (usft) Survey Tool Name Annotation (ft) (ft) (ft) i 36.50 0.00 0.D0 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 D.DO 0.00 UNDEFINED 60.26 0.33 231.64 60.26 -28.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.01 GYD-CT-DMS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 -0.36 5,945,543.27 317,059.61 0.22 -0.14 GYD-CT-DMS(1) 263.26 0.56 211.72 263.25 174.55 -1.26 -0.70 5,945,542.54 317,059.25 0.24 -0.43 GYD-CT-DMS(1) 296.26 OAS 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96 1.31 4).49 MW)-IFR-AK-CAZ-SC (2) r 390.15 1.24 252.95 390.13 301.43 -2.46 -2.50 5,945,541.40 317,057.42 0.64 -0.D6 MWD+1FR-AK-CAZ-SC (2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 2.03 MWD+IFR-AK-CAZ-SC (2) 577.56 3.84 299.00 577.36 488.66 0.13 -9.59 5,945,544.16 317,050.40 1.76 6.69 MW0+1FR-AK-CAZ-SC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 14.14 MWD+IFR-AK-CAZSC(2) 766.06 7.00 304.80 764.99 676.29 9.88 -24.57 5,945,554.26 317,035.66 1.63 24.07 MWD+IFR-AK-CAZSC(2) 860.61 8.03 306.69 858.72 770.02 17.11 -34.60 5,945,561.73 317,025.81 1.12 36.22 MWD+IFR-AK-CAZSC(2) 955.24 8.% WTU 952.31 863.61 25.53 -05.76 5,945,570.42 317,014.86 0.99 tI 50.00 MWD+IFR-AK-CAZSC(2) } 1,048.71 10.08 308.87 1,044.50 955.80 35.08 5291 5,945,580.26 317,002.94 1.23 65.30 MWD+IFR-AK-CAZ-SC (2) ' 1,143.88 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 83.02 MWD+IFR-AK-CA7-SC (2) t 1,236.25 12.95 31096 1230.19 1,141 49 59.31 SZ07 5,945,605.19 316,974.39 1.50 102.94 MWD+IFR-AK-CA7-SC (2) : 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945,620.06 316,957.95 1.25 124.99 MWD+IFR-AK-CAZ-SC (2) 1427.45 14.70 30804 141378 1,325.OB 8866 -122.08 5,945,635.36 316,940.10 0.89 148.33 MWD+IFR-AK-CAZ-SC(2) 1.521.38 15.39 305.44 1504.49 1,415.79 103.23 -14162 5,945650.42 316.920.92 1.03 172.34 MWD+IFR-AK-CAZ-SC(2) 8/152018 4'59:36PM Page 3 COMPASS 5000.14 Build 85 BA, �(ER U6NE5 Annotation 13-3/B" x 16" 8/15/2018 4'59:36PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report _ _ --- Company: .------------- ConomPhillips(Alaska) Inc. -WNS Local Coordinate Reference Well MT6-05 Project: Western North Slope TVD Reference: MTS -05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Map Map vertical MD Inc Azi TVD TVDSS +N/S +E/_W DLS (usft)(°) (°) (usft) (usft) (usft) (usft) Northing Easting P100') Section Survey Tool Name (ft) (ft) (ft) 1,616.89 14.91 304.96 1,596.68 1,507.98 117.62 -162.02 5,945,665.30 316,900.88 0.52 196.82 MWD+IFR-AK-CAZSC(2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 220.65 MWD+IFR-AK-CAZSC(2) 1,805.77 16.56 306.15 7]78.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 246.23 MWD+IFR-AK-CAZSC(2) 1,899.91 18.01 307.58 1,868.62 1,779.92 163.82 -225.19 5,945,713,02 316,838.85 1.60 273.81 MWD+IFR-AK-CAZSC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 291.94 MWD+IFR-AK-CAZSC(2) 2,014.00 19.29 30293 1,976.66 1,887.96 186.34 -254.03 5,945,736.24 316,810.51 0.83 310.04 MWD+IFR-AK-CAZSC(3) 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 322.06 MWD+IFR-AK-CAZ-SC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 335.18 MWD+IFR-AK-CAZ-SG(3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 301.15 5,945,774.29 316,764.37 2.55 369.20 MWD+IFR-AK-CAZ-SC(3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 331.10 5,945.798.93 316,735.00 2.78 407.17 MWD+IFR-AK-CAZ-SC (3) 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 363.43 5,945,825.26 316,703.30 1.60 447.96 MWD+IFR-AK-CAZ-SC (3) 2,467.33 27.46 308.78 2,391.02 2,302.32 299.60 397.30 5,945,852.94 316,670.10 O.B5 490.75 MWD+IFR-AK-CAZ-SC (3) 2,559.45 29.82 306.63 2,471.87 2,3x3.17 326.58 4x2.25 5,945,880.75 316,635.82 2.80 534.37 MWD+IFR-AK-CAZ-SC (3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 469.44 5,945,909.21 316,599.32 1.14 579.96 MWD+IFR-AK-CAZ-SC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 508.33 5,945,939.39 316,561.15 1.05 627.90 MWD+IFR-AK-CAZ-SC(3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.55 677.31 MWD+IFR-AK-CAZSC(3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 -587.97 5,946,002.74 316,483.03 0.12 727.32 MWD+IFR-AK-CAZSC(3) 3,028.87 32.99 308.00 2,871.15 2,782.45 476.32 528.35 5,946,035.20 316,443.43 0.73 777.94 MWD+IFR-AK-CAZSC(3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.28 5,946,067.97 316,403.28 0.64 829.18 MWD+IFR-AK-CAZSC(3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946,101,09 316,362.09 1.33 881.36 MVJD+IFR-AK-CAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 935.05 MWD+IFR-AKLAZSC(3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946169.49 316,276.14 0.79 989.73 MWD+IFR-AK-CAZSC(3) 3,500.89 36.47 306.40 3,257.86 3,169.16 640.06 543.65 5,946,204.11 316,232.18 0.59 1,044.89 MWD+IFR-AK-CAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 588.51 5,946,238.62 316,188.14 0.74 1,100.02 MWD+IFR-AK-CAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 A34.17 5,946,274.11 316,143.34 0.65 1,156.39 MWD+IFR-AK-CAZSC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742,40 982.28 5,946,309.78 316,096.09 2.97 1,214.53 MWD+FR-AK-CAZSC(3) 3,877.30 40.94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1.274.17 MND+IFR-AK-CAZSC (3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084,82 5,946,380.33 315,995.24 0.08 1,334.48 MND+IFR-AK-CAZSC (3) 4,065.45 40.97 303.86 3,695.06 3,606.36 644.47 -1,135.92 5,946,415.55 315,944.98 0.32 1,394.30 MWD+IFR-AK-CAZSC(3) 4,159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,45176 315,893.96 1.20 1,455.37 MWD+IFR-AK-CAZ-SC(3) 4,254.03 43.41 305.40 3,834.89 3746.19 915.89 -1240.34 5,94648948 315,84233 1.69 1517.97 MWD+IFR-AK-CAZ-8C(3) BA, �(ER U6NE5 Annotation 13-3/B" x 16" 8/15/2018 4'59:36PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope i Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 i Design: MT6-05 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MTIi05 MT6-05 Actual @ 88.70us%(Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production ID eA, KE H� S �9�ri ' Survey Map Map Vertical MD ;s Inc Azl TVD TVDSS +N/ -S +E/_W Northing Easting DLS Section (use) (°) (°) (usft) (use) (usft) (usft) (°n9D') Survey Tool Name Annotation (ft) (ft) (ft) 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -1,292.10 5,946,528.52 315,791.50 2.04 1,561.01 MWO+IFR-AK-CAZSC(3) { 4,444.53 45,64 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571]8 315,736.38 0.6B 1650.06 MWD+IFR-AK-CAZ-SC(3) q 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,720.07 MWD+IFR-AK-CAZSC(3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,787.22 MWD+IFR-AK-CAZ-SG(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 075 1,852.27 MWD+IFR-AKCAZ-SC(3) 4,824.17 45.60 304.58 4,235.60 4,146.90 1,154.17 -1,568.46 5,946,735.64 315,520.11 0.36 1,916.62 MWD+IFR-AK-CAZ-SC(3) I 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,982.62 MWD+IFR-AK-CAZ-SC (3) 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813]3 315,410.16 0.33 2,048.27 MWD+1FR-AK-CAZ-SC (3) p 4 5,106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1.735.77 5,946,852.98 315,355.62 0.42 2,113.96 MWD+IFR-AK-CA7-SC (3) £ 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,94$892.64 315,300.93 0.22 2,179.97 MWD+IFR-AK-CAZ-SC (3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,246.00 MWD+IFR-AK-CA7-SC (3) Ei t r 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.28 2,311.99 MWD+IFR-AK-CAZ-SC (3) XE 5,463.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1,958.1D 5,947,009.17 315,13203 0.21 2,376.37 MWD+IFR-AK-CAZ-SC (3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,442.19 MWD+IFR-AK-CAZ-SC (3) i 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,507.60 MWD+IFR-AK-CAZ-SC (3) 5,766.67 45.12 306.17 4,896.71 4,808.01 1,533.09 -2,123.09 5,947,127.89 314,974.88 0.95 2,573.16 MWD+IFR-AK-CAZ-SC (3) i 5,851.26 45.08 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,639.16 MWD+IFR-AK-CAZ-SC (3) i 5,953.99 45.13 307.58 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,703.99 MWD+IFR-AK-CA7-SC (3) 6,048.44 45.04 307.59 5895.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,770.06 MWD+IFR-AK-CAZ-SC (3) 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,835.85 MWD+IFR-AK-CAZ-SC (3) 6,235.05 45.06 307.01 5,227.45 5,138.75 1.734+21 -2,386.78 5,947,335.35 314,716.18 0.68 2,900.53 MWD+1FR-AK-CAZ-SC (3) 6,329.17 45.06 306.63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947,376.56. 314,653.83 0.29 2,966.19 MWD+IFR-AK-CAZ-SC(3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1813.94 -2,493.85 5,947,417.65 314,611.08 0.16 3,032.05 MWD+1FR-AK-CAZSC(3) Y 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2,547.50 5,947,458.46 314,558.40 0.09 3,097.64 MWD+IFR-AK-CAZSC(3) 6,612.19 45.05 306.15 5,493.76 5,405.06 1,893.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,163.47 MWD+IFR-AK-CAZSC(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3,228.92 MWDAFR-AKCAZSC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3294.97 MWD+IFR-AK-CAZSC(3) 6,896.14 45.10 305.70 5,694.24 5,605.54 2,011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,%1.15 MWD+IFR-AKCAZSC(3) 6,991.21 45.07 305.68 5,761.36 5,672.66 2,050.40 -2,818.90 5,947,661,92 314,291.89 0.03 3,427.27 MWD+IFR-AK-CAZ-8C(3) 7,085.78 45.08 305.19 5,828.15 5,739.45 2,089.22 -2,873.46 5,947,702.06 314,238.29 0.37 3,492.97 MWD+IFR-AKCAZSC(3) , 7,179.83 45.10 305.01 5,894.55 5,805.85 2,127.52 -2,927.95 5,947,741 66 314,184.75 0.14 3,558.26 MWD+IFR-AKCAZ-SC (3) 8/152018 4:59:36PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BAKER ConocoPhillips Definitive Survey Report dry' Company: ConomPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey 8/1512018 4'59:36PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) P) (`) (usft) (waft) Waft) lush) Survey Tool Name Annotation (ft) (fti (ft) 7,273.52 45.05 304.86 5,960.71 5,872.01 2,165.51 -2,982.33 5,947,760.96 314,131.31 0.13 3,623.24 MWD+IFR-AK-CAZ-SO(3) 7,368.38 45.9 305.02 6,027.70 5,939.00 2,203.97 -3,037.39 5,947,820.74 314,077.21 0.13 3,689.02 MWD+IFR-AK-CAZSC(3).. 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 -3,091.64 5,947,850.21 314,023.90 0.15 3,754.04 MWD+IFR-AK-CAZSC(3) 7,555.32 45.01 304.78 6,159.73 6,07L03 2,280.00 -3,145.72 5,947,899.37 313,970.76 0.34 3,818.72 MWD+IFR-AK-CAZSC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 -3,200.60 5,947,936.63 313,916.82 0.19 3,884.01 MWD+IFR-AK-CAZSC(3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 .3,254.29 5,947,977.43 313,864.06 0.66 3,948.17 MWD+IFR-AK-CAZSC(3) 7,836.69 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,948,017.84 313,810.38 0.35 4,014.13 MWD+IFR-AK-CAZSC(3) 3 7,93075 45.27 305.88 6,424.41 6,335.71 2,433.69 -3,363.13 5,948,058.29 313,757.16 0.05 4,079.82 MWD+IFR-AK-CAZ-SC(3) 8.024.98 45.26 306.66 6,490.73 6,402.03 2,473.29 -3,417.09 5,948,099.19 313,704.18 0.59 4,145.69 MWD+IFR-AK-CAZSC(3) 8,118.93 45.30 307.04 6,556.89 6,468.14 2,513.32 -3,470.51 5,998,140.50 313,65175 0.29 4,211.49 MWD+IFR-AK-CAZ-SC(3) 8,212.40 45.10 306.82 6,622.70 6,534.0 2,553.17 3,523.53 5,948,181.63 313,599.72 0.27 4,276.89 MWD+IFR-AK-CAZ-SC(3) 8,306.99 45.06 306.73 6,689.49 6,600.79 2,593.27 -3,577.18 5,948,223.01 313,547.06 0.08 4,342.89 MWD+IFR-AK-CAZ-SC (3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 -3,630.98 5,948,263.96 313,494.25 0.50 4,408.68 MWD+IFR-AK-CAZ-SC (3) 8,495.22 45.06 305.99 6,822.49 6,733.74 2,671.99 -3,684.69 5,948,304.31 313,441.50 0.05 4,473.98 MWD+IFR-AK-CAZ-SC (3) 8,589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 -3,739.01 5,948,344.79 313,388.15 0.29 4,539.78 MWD+IFR-AK-CAZ-SC (3) 8,685.37 45.05 305.58 6,956.81 6,868.11 2,750.49 3,793.96 5,948,385.44 313,334.18 0.03 4,606.12 MWD+IFR-AK-CAZ-SC (3) 8,779.66 45.06 30670 7,023.42 6,93472 2,789.84 3,847.86 5,948,426.09 313,281.26 0.84 4,671.76 MWD+IFR-AK-CAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 -3,901.48 5,948,46265 313,228.63 0.31 4,73288 MWD+IFR.AK-CAZSC(3) 8,894.81 45.04 307.55 7,104.76 7,016.06 2,838.87 -3,912.96 5,948,476.68 313,217.37 1.49 4,752.13 MWD+IFR-AK-CAZSC(3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 -3,923.22 5,946,464.85 313,207.30 0.78 4,769.93 MWD+IFR-AKLAZSC (4) 9-5/8"%12-V4" 8.968.80 45.18 W&M 7.156.98 7,068.28 2,871.11 -3,954.29 5,948,509.91 313,176.83 078 4,803.96 MWD+IFR-AK-CAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 -3,999.04 5,948,546.27 313,132.93 0.68 4,860.35 MWD+1FR-AKCAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 4,051.35 5,948,588.75 313,081.66 0.66 492626 MWD+IFR-AKCAZ-SC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,939.85 4,103.71 5,948,632.24 313,030.35 1.02 4,992.92 MWD+IFR-AKCAZ-SC(4) 9,332.26 48.44 311.66 7,411.19 7,322.49 3,034.66 4,155.97 5,948,678.30 312,979.20 3.40 5,061.40 MWD+IFR-AK-CAZ-SC (4) 9,426.43 51A9 311.06 7,471 75 7,383.05 3,082.29 4.210.09 5,948,72223 312,926.26 3.28 5,133.19 MWD+IFR-AK-CAZ-SC (4) '.. 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4266.03 5,948,777.27 312,871.52 2.72 5,207.02 MWD+IFR-AKCAZSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5,948,829.46 312,814.26 2.03 5,284.13 MWD+IFR-AKCAZSC(4) 9,70662 59.30 312.69 7,631.91 7,543.21 3.233.78 4,382.70 5,948,882.85 312,757.39 3.99 5,361.88 MWD+IFR-AKCAZSC(4) 9,801.05 61.09 315.59 7,678.86 7,590.16 3,290.84 4,441.48 5,948,941.33 312,700.01 3.27 5,44374 MWD+IFR-AKCAZSC(4) 9,895.24 63.67 31804 7,722.52 7,63382 3,35170 4498.56 5,949,003.55 312,644.43 3.58 5,527.17 MPID+)FR-AK-CAZ-SC(4) 8/1512018 4'59:36PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips 41 ConoCoPhilllps Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 i Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) _. Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 68.70usft (Actual D19) Well: MT6-05 North Reference: True 3 Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: 3 MT6-05 Database: EDT 14 Alaska Production Survey 8/1512018 4: 59 36P Page 7 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) lusft) (usft) (usft) ("/100') Survey Tool Name Annotation (ft) (ft) (ft) 9,98962 65.86 320,87 7,762.77 7,67407 3,41657 4,554,04 5,949,069.74 312,590.55 3.57 5,61242 MWD+IFR-AK-CAZ-SC(4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 4,607.37 5,949,139.19 312,538.89 3.51 5,698.59 MWD+IFR-AK-CAZ-SC (4) 10,178.42 71.79 324.53 7,83143 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,787.09 MWD+IFR-AK-CA7SC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 4,710.97 5,949,286.90 312,438.85 2.18 5,875.28 MWD+IFR-AK-CAZSC(4) 10,356.04 75.73 327.31 7,884.53 7,795.83 3,705.72 4,760,88 5,949,363.81 312,390.80 2.91 5,964.58 MWD+IFR-AK-CAZSC(4) 10,460.54 77.60 329.31 7,906.32 7,817.62 3,783.96 4,809.18 5,949,443.20 312,344.42 2.86 6,054.59 MWD+IFR-AK-CAZSC(4) 10,555.35 79.69 330.90 7,924.99 7,836.29 3,86454 4,855.50 5,949,524.87 312,300.07 275 6,144.94 MWD+IFR-AK-CAZSC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,607.76 312,257.14 1.90 6,235.25 MWD+IFR-AK-CAZ-SC(4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,325.85 MWD+IFR-AK-CAZ-SC(4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,986.88 5,949,776.06 312,174.76 114 6,415,38 MWD+IFR-AK-CAZ-SC (4) 10,933.50 82.85 332.68 7,977.79 7,889.09 4,195.72 -5,030.07 5,949,860.17 312,133.61 0.71 6,505.40 MWD+IFR-AK-CAZ-SC (4) 10,977.58 82.88 332.54 7,983.26 7,89455 4,234.59 -5,050.12 5,949,899.52 312,114.51 0.77 6,547.41 MWD+1FR-AK-CAZ-SC (4) 7" x 8-3/4" 11,028.48 82.91 332.15 7,989.56 7,900.86 4,279.33 -5,073.56 5,949,944.81 312,092.16 0.77 6,596.01 MWD+IFR-AK-CAZSC(4) TIP 11,106.0 82.89 332.81 7,999.14 7,910.44 4,347.55 5,109.11 5,950,013.87 312,058.29 0.85 6.669.98 MWD -INC -ONLY (INC110') (5) KOP-TOWS 11,119.05 84.55 331.84 8,000.57 7,911.87 4,359.03 5,115.13 5,950,025.50 312,052.54 14.71 6,682.46 MM -INC -ONLY (INC110') (5) nteprolated Azimuth 11,212.00 84.82 325.68 8,D09.19 7,920.49 4,438.13 5,163.11 5,950,10573 312,006,50 6.61 U72.87 MWD -INC ONLY (INC>10°)(5) (nteprolated Azimuth 11,264.03 85.49 322.23 8,013.58 7,924.88 4,480.04 5,193.61 5,950,148.36 311,977.03 6.73 6,824.27 MAD -INC _ONLY (INC>10°)(5) Inteprolated Azimuth 11,358.55 89.05 319.48 8,018.09 7,929.39 4,553.24 -5,253.20 5,950,222.99 311,919.24 4.76 6,918.39 MWD -INC ONLY(INC>10°)(5) Inteprolated Azimuth 11,453.90 91.38 316.71 B,D17.73 7,929.03 4,624.19 5,316.87 5950,295.46 311,857.31 3.80 7,013.69 MWD+IFR-AK-CAZ-SC (6) 11,549.18 91.92 317.12 8,014.99 7,926.29 4,693.75 -5,381.93 5,950,366.57 311,793.97 0.71 7,108.93 MWD+IFR-AK-CAZ-SC (6) 11,644.55 92.44 320.77 8,011.36 7,922.66 4,765.60 -5,444.51 5,950,439.92 311,733.16 3.86 7,204.13 MWD+4FR-AK-CAZ-SC (6) 11,739.78 93.27 324.15 8,006.61 7,917.91 4,841.01 -5,502.45 5,950,516.70 311,677.06 3.65 7,298.72 MWD+IFR-AK-CAZ-SC(6) 11,834.89 91.02 326.98 8,003.05 7,914.35 4,919.38 -5,556.19 5,950,596.36 311,625.25 3.80 7,392.57 MW0+1FR-AK-CAZSC (6) 11,930.25 88.12 330.86 8,00377 7,915.07 5,001.03 -5,605.40 5,950,679.17 311,578.04 5.08 7,485.68 MWD+IFR-AK-CAZSC(6) 12,025.83 89.93 335.47 B4O05.39 7,916.69 5,086.27 5,648.53 5,950765.43 311,537.00 5.18 7,577.22 MAV+IFR-AK-CAZSC(6) 12,121.14 89.99 336.06 8,005.46 7,916.76 5,173.18 5,687.65 5950,853.26 311,500.00 0.62 7,657.22 MWD+IFR-AK-CAZ-SC(6) 12,216.12 88.90 338.34 8,006.38 7,917.68 5,260.73 -5,724.45 5,950,941.67 311,465.34 2.66 7,756.08 MWD+IFR-AK-CAZ-SC(6) 12,311.41 88.17 338.74 8,008.92 7,920.12 5,349.39 5,759.30 5,951,031.14 311,432.65 0.87 7,844.40 MWD+IFR-AK-CAZ-SC(6) 12,406.40 88.42 337.65 8,011.64 7,922.94 5,437.54 -5,794.57 5,951,120.12 311,399.54 1.18 7,932.65 MWD+IFR-AK-CAZSC(6) 12,501.61 89.62 336.72 8,013.27 7,924.57 5,525.28 -5,831.48 5,951,208.73 311,364.77 1.59 8,02173 MWD+IFR-AK-CAZSC(6) 12,59670 9443 340.61 8,009.91 7,92121 5,61376 -5,866.04 5,951,298.01 311,332.37 650 8,10972 MWO+IFR-AK-CA2-SC(6) 8/1512018 4: 59 36P Page 7 COMPASS 5000.14 Build 85 ConocoPhillips SAF�uGtlEs ConocoPhillips Definitive Survey Report 9 . Company: ConowPhillips(Alaska) Inc. -WNS project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-05 MTS -05 Actual @ 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual D19) True Minimum Curvature EDT 14 Alaska Production Annotation 4-1/2" x 6" - MTS -05 T2.3 8(1512018 4 59:36PM Page 8 COMPASS 5000.14 Suits 85 Map Map Vertical MD Inc Azi TVD TVDSS -N/-S +EI -W Northing Easgn g DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name (ft) (ft) (ft) 12,691.56 92.56 342.26 8,004.13 7.915.43 5,703,51 -5,89619 5,951,388.46 311,304.42 2.63 8,19560 MMD 11FR-AK-CAZ-SC(6) 12,787.02 92.78 343.21 7,999.68 7,910.98 5,794.57 5,924.49 5,951,480.17 311,278.34 1.02 8,281.16 MWD+IFR-AK-CAZSC(6) 12,881.97 89.63 341.15 7,997.69 7,908.99 5,884.92 5,953.53 5,951,571.20 311,251.50 3.95 8,36673 MWD+IFR-AK-CAZ-SC(6) 12,977.36 88.10 338.17 7999.58 7,910.88 5,974.34 -5,986.68 5,951,661.39 311220.54 3.51 8,454.42 MWD+1FR-AK-CAZ-SC(6) 13,073.05 87.96 337.16 8,002.95 7,914.25 6,062.79 -6,023.02 5,951,750.69 311,186.36 1.08 8,543.63 MWD+IFR-AK-CAZ-SC (6) 13,168.20 89.10 335.70 8,005.47 7,916.77 6,149.97 -6,061.05 5,951,838.76 311,150.46 2.01 8,633.07 MWD+IFR-AK-CAZ-SC (6) 13,263.49 88.87 333.45 8,007.16 7,918.46 6,236.01 -6,101.95 5,951,925.77 311.111.66 2.37 8,723.65 MWD+IFR-AK-CAZ-SC (6) 13,359.31 87.92 332.72 8,009.84 7,921.14 6,321.42 -6,145.31 5,952,012.20 311,070.39 1.25 8,815.47 MWD+1FR-AK-CAZ-SC(6) 13,454.46 93.01 333.73 8,009.07 7,920.37 6,406.33 -6,188.16 5,952,098.12 311,029.62 5.45 8,906.58 MWD+1FR-AK-CAZSC(6) 13,549.84 94.85 333.95 8,002.54 7,913.84 6,491.74 -6,230.11 5,952,1&1.52 310,989.76 1.94 8,997.43 MWD+IFR-AK-CAZSC(6) 13,645.06 95.04 333.96 7,994.33 7,905.63 6,576.97 -6,271.76 5,952,270.73 310,950.19 0.20 9,087.94 MWD+IFR-AK-CAZSC(6) 13,740.32 95.61 333.86 7,985.49 7,896.79 6,662.15 -6,313.47 5,952,356.90 310,910.56 0.61 9,178.47 MWD+IFR-AK-CAZSC(6) 13,785.DD 95.61 333.86 7,981.12 7,892.42 6,702.07 -6,333.07 5,952,397.28 310,891.95 0.00 9,220.92 PROJECTED to TD Annotation 4-1/2" x 6" - MTS -05 T2.3 8(1512018 4 59:36PM Page 8 COMPASS 5000.14 Suits 85 THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Greater Mouses Tooth Field, Lookout Oil Pool, MT6-05 Permit to Drill Number: 218-045 Sundry Number: 318-395 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Per 20 AAC 25.080, only drilling waste may be disposed within the 9-5/8" X 13-3/8" annulus of well MT6-05. 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. 4k DATED this 1 L day of November, 2018. Sincerely, Hollis S. French Chair, Commissioner OV 101010 RgDM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ED U°dP 1120118 0 SCC 1. Operator 3. Permit to Drill Name: 218-045 ' ConocoPhillips Alaska 4. API Number: 50-103-20771-00-00 ' 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska MT6-05 6. Fiel : '�- G'!f"iuc>:+t/i r Unit- A Pool 7. Publicly recorded wells B. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: st_ f 3•(� MT6-03, MT6-08 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,200' MD and 1190' TVD • None 11. Previous volume disposed In annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure al shoe: None densities range from diesel to 1201gal 1861 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbis. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- wntaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start dale: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 1-Ocl-1 B added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (include MD and TVD) 21 Cement Bond Log (if required) ❑ FIT Records w/LOT Graph p Surf. Casing Cementing Data O Other III previous authorization for new Product cleanup fluids for CDi and CD2 18. 1 hereby certify that the foregoingis true and correct to the best of my knowledge. Signature: AZe04 [[ Title: Printed Phone Name: Chip Alvord Number: 265.6120 Date: � 11 d 2a 16 Commission Use Only Conditions of approval: LOT review and approval: Subsequent form required: 10--4.Z3 Approval number: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ' • 140, toe 1/TL 811311,RW nVJ I RUU 11U1VJ V V RCVCttJC n 1 u JWAit In Duplicate L(g RRD �GR�tg� �ITRIGINALNS'"06 : ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 10th, 2018 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501-3539 r ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well MT6-05 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that MT6-05 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 MT6-05 approximately October 1', 2018. 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 12-1/4" x 9-5/8" casing annulus 10. List of wells on MT6 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within'/4 mile radius at AOGCC: N/A 12. Information regarding remaining wells within '/4 mile radius included in sundry package: MT6-03, MT6-05, MT6-08 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 (16.1) occurred at a lower equivalent mud weight than the casing shoe FIT (18.1 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 Greg Hobbs at 263-4749 or Chip Alvord can also be reached by calling 265-6120. Sincerely, Greg Hobbs Drilling Engineer cc: MT6-05 Well File Chip Alvord Annulus Disposal Transmittal Form - Well MT6-05 AO CC Regulations, 20 AAC 25.080 6 1 IDesignation of the well or wells to receive drilling wastes: MT6-05 2 The depth to the base of freshwater aquifers and permafrost, There are no freshwaer aquifers in the affected area of the if present. Lookout Oil Pool. Estimated base of Permafrost = 1190' ' TVD(RKB) 3 A stratigraphic description of the interval exposed to the open the shales of the Upper Seabee formation (.Above C-30) annulus and other information sufficient to support a provides the upper barrier and the shales of the Lower Seabee commission finding that the waste will be confined and will Formation (below C-30) provide a lower barrier. Calculated not come to the surface or contaminate freshwater. water salinities of the Cretaceous and older stratigraphy sections range from 13,000 to 31,000 ppm. There are no freshwater aquifers in the affected area of the LOP (Lookout Oil Pool)(Ref. AOGCC Area injection Order No. 40, Pg. 7, May 29, 2018) 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 I 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 Lk/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, thud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1R2 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 1861 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 / FII' 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 summaay 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 7921' MD in the intermediate casing depth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarlxm hearing 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 MT6-06, MT6-04, MT6-09, MT6-07, MT6-02, MT6-01 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 MT6-05 Date 9/10/2018 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is 1,500 12.0. 0.434 V --z o -1-v psi ppg psi/ft String Size 9.625 in Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft ppf 8 1 0 p y p ri Grade L 80 Header Pressure (for wells on gas lift) 1,000 psi 3,090 psi Paouapuss% aximum Fluid Density to avoid Burst of Surface Casing psi Top of Cement 6,424 Pbur M% = PHYdrostAic + PAPpInd - PFmmazion4,267 Gas Gradient 0.07 psi/ft [LI,977 = ( 1,977 * 0.052 - M Wma )+ 1500 - ( 0.4337 • 1,977JTVD Header Press 1,000 psi rvlw.. = 35.3 pPg Surface Casing Strin¢ Size 13.375 in Weight 68 ppf F Grade L 80 'a 'a Pbura00011. 5,020 psi Pb=t85% 4,267 psi Depth of Shoe 1,977 ft tz Q FIT/LOT @ Shoe 18.1 ppg or 1,861 psi FIT/LOT for Annulus 16.1 ppg (/ ,m Max Surf. Pressure 1,500 psi Est. @ 7,921' MD 6,424TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pco11apu85% = Pxyd,. Matic + PA,bed - PG.Gadlent - PHeaaer 2,627 =( 6,424' 0.052 ' M W... )+ 1,500 - ( 0.0700 * 6,424 ) - 1,000 MW... = 7.7 PPB 3.5 "Tubing 2nd Casing String Size 9.625 in 7,123 TVD Weight 40 ppf 8 1 0 p y p ri Grade L 80 Pcollapseto0�h 3,090 psi Paouapuss% 2,627 psi Top of Cement 6,424 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 1,977 *.052 * 18.1 ) Pmax allowable — 1,861 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Well MT6-05 Date 10/30/2018 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 3,0 - Oct'I8 Assumptions _ Maximum injection pressure of 1,500 psi CG wa-M e rt� Maximum density of the injection Fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft 1 Fluid Gradient in tubing/casing annulus 0.36 psi/0 Header Pressure (for wells on gas lift) NA psi 13-3/8" Casing 2,014 MD 1,977 TVD TOC 2nd string Est. @ 7,921' MD 6,424' TVD 9-5/8" Casing 8921 MD * 7,125 TVD POC 3rd 9,664' MD string Est, @ 7,609' TVD )c 11,173' MD 8007' TVD 13b.ut85 0 — PHydmsnnic + PAPplied - PFo 4,267 = ( 1,977 * 0.052 * MW,,,a, MW... = 35.4 PPg )+ 1500 - ( 0.4337 * 2,014 ) Surface Casing String Size 13.375 in Weight 68 ppf Grade L 80 Pbuu000% 5,020 psi Pbuut8.5% 4,267 psi Depth of Shoe 1,977 ft FIT/IAT @ Shoe 18.1 ppg FIT/LAT for Annulus 16.1 ppg Max Surf. Pressure 1,500 psi or 1,861 psi Maximum Fluid Density avoid Collapse of 2nd Casing Strine Pconap css%= PHydtostadc + PAppucd - Pnuidcrndim 2,627 = ( 6,424- 0.052 * M W,oa, ) + 1,500 - ( 0.3600 * 6,424 ) M W„p, = 10.3 ppg 2nd Casing String Size 9.625 in Weight 40 ppf Grade L 80 Pcouapscl0o^,0 3,090 psi Pcollapsea5?b 2,627 psi Top of Cement 6,424 11 Fluid Gradient 0.36 psi/ft Max Surf. Pressure 1,500 psi Header Press NA psi Maximum Anticipated Pressure at Surface Casing Shoe P.. anm�able = Shoe TVD Depth *.052 * Shoe FIT/LOT Pma. anoWamc= ( 1,977 *.052* 18.1 ) Pmex ellowabk — 1,861 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". C m Wt. %,, s, V4 (n ecr�tmw bt'eS5V-/e qo.r- vva XI ✓,, L,W(- Sot>G/ -e a3 I%QYI0US Yl' V tO191D k�_S MT6-05 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW ( ) Injection Pressure (psi) MW ( ) Injection Pressure (psi) MW ( ) Injection Pressure (psi) 6.8 1,212 8.8 11006 10.8 800 6.9 15201 8.9 996 10.9 790 7.0 11191 9.0 986 11.0 780 7.1 11181 9.1 975 11.1 770 7.2 11171 9.2 965 11.2 759 7.3 11160 9.3 955 11.3 749 7.4 1,150 9.4 944 11.4 739 7.5 11140 9.5 934 11.5 729 7.6 11129 9.6 924 11.6 718 7.7 1,119 9.7 914 11.7 708 7.8 11109 9.8 903 11.8 698 7.9 1,099 9.9 893 11.9 687 8.0 1,088 10.0 883 12.0 677 8.1 1,078 10.1 872 12.1 667 8.2 11068 10.2 862 12.2 657 8.3 11057 10.3 852 12.3 646 8.4 1,047 10.4 842 12.4 636 8.5 1,037 10.5 831 12.5 626 8.6 11027 10.6 821 12.6 615 8.7 1,016 1 10.7 1 811 1 12.7 605 SURFACE CASING SHOE SEPARATION FROM MT6-05 planned MT6-05 planned x v Surface Casing Shoe ASP 4 Coordinates NAD 27: 316628.85 5945721.18 Wells Ann. Details @ Disp. Source Ann. Vol. AOGCC Permit # Permit Date well •' Distance from Object Start Date End Date well' Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surface Surf LOT casing TVD (ppg) (ft) Annular LOT (ppg) Comments MT6-03 N 299 317125.92 5945754.12 1 i, 1 2052 - 14.5 2078' MD MT6-05 N 0 316828.85 5945721.18 18.1 1977 16.1 2014' MD MT6-08 N 87 316910.89 5945693.30 18.0 1984 Not an annular in ectlon candidate MT6-06wp05 181 316859.42 5945899.85 M7.6-04wp02 303 317028.00 5945493.08 MT6-09wp02 1 134 316821.25i 5945587,261 1 MT6-07wp02 3301 316903.651 5945400.13 MT6-02wp02 3 317148.51 1145672.151 1 MT6-01wp02 39223 317219.47 5945756.37 ' Lateral distance in feet, between surface casing shoes, in the X -Y plane Note that this sheet is not the definitive record for annular disposal volumes Last Update 911/2018 All wells highlighed in blue are within a quater mile 1320 August 01 3500 2100 c 4f 0 01400 0 o 700 z 0 U) 0 -700 -1400 DSIR P�bg 9� _s'(6A Quarter Mile View -2800 -2100 -1400 -700 0 700 --7- 1400 - 7.o;d and Shannbn,, £ °new -product" clean up fluids from the You. have r'glAemted tp dispose o inutine miximg c5 mud and cement at Alpine as well as the clean up fluids;result resulting from tion for using 0 d. cleaning out the tanks at the mud plant in preparation .cl bate irnx The had previously approved disP°sing 'of the °new product" clean up e [loins .via annular disposal at CD 1 pad• al options Due�to the geological setting at 'stied Class 1 and Claes 2 dinAoa are Liu�ited.. Phillips,ptcde.cessor, ti�[4, had e�teblisYied the li.mitziti.orr of 40,090to Coruni al tions_ ssiori's sob-"9.sf2icti.an an2l.annular disposal'wasapfiroved as op" the approved practiral and environmental alternative• -- In the request's the waste fluids are no di..irrent- than previously pp and. d ve]opu�Cknt activitieA. at Alpine- ' ,,}Fe the result of tlia. ongoing e The c`.ommis'sioriers haveautboriaed me t9 send You thio me§cage• SY copy OF this email, Phillips is authorized to dispose of Clean 11p fluids as described in your c nail - escS.drs. please call with any 'au 'Pam "winder, PE ,Or. petroleum Engineer / >WGCC RLP 'Env CUord wrote: kaunder, -Lquested > Aa noted in the -attached email, Tom Monson previously 3 i^xations via annular. > ouchori,:atioq to-dielpose of new_Product clean up fluids such.as Cement > rihsate, and mud. arid. brine pit rinses from mi2Drj�jg operations injection i.n.permitted.vm""7,7:s at the Alpine CD2 Drill 5199 basRdton theow. ., Ao6CC approved such disposal at tile CD3- Drill Sited e o > integral relationship of the mud mixing facility and the on-site drilling > operation. > Phillips would like to coitti.nui.ng persuing. this recr1e.e". Sigationaro clean. > out of cd'ou at thc:mud mixing facility; must dccur.in.,preparation,t;or the. a ank rin temporary use of,oil based mud products Al; hlpine in the coming months, > Tile availability of annular disposal tascr this Procesam an option s t(TyPically£lrouti ed > similar wastes would greatly > rinses are beneficially xeusedr however., there is a concern about t c > potential v_benL•lcy of fluid tbac'c'ould be gener"atsd during this largo ticale > cleaii up process.} ' > contain either new and used mud product(; may, be injected in > Tanks a:, the mud mixing facility may xodtre t would > products- Though rinses in conte with used pr sij, well (WD -021, whefe chars is > the permitted class 7:1 disposAl. well, (CDl.9"lil rinses .o new A > patent}"ally be routed to the clan ..i dispp l all. a diPfi.culty managing soJ;id'a content. The aliimS I Well is a critical compromise to this > , dirfi5 fof facility i-nfTaStr,,,tura, being the disposal vocation o- referred waste management• > domestic effluent, and it is a priority to prevent 'any > disposal' facility• Annular disPosml. presents a p > alternative in this case. t > 4 ploaee do not carnets Vi.a' a:aail or phona at (907). 670-4200 > Thank you very much for yah= aoaisideYatirizi 6E this regiaest- >' hesitate to Cc me or iqY 'a0, > if you have questions or need additional information. > > Shannon Donnelly > Alpi-ne'ield' ;nvironmenL-ai CoozYiinaLox• > (907) 670-4200 y tzprwarded by'ALP Snv Coord7PPC0 on.11J02/O1 X2:50 PM > ALP Env Coord 000/ni 12:45 PM i To:.to'.'.'�'nF!dn¢er0edmi.n.St-a.tt.ak.us > Cc: ' Subject: Request to imiect Cement Rinsacn at CD2 > Dcar Mr. Maundbrr fluids from a:ud and brine tniXYnc� > injeotion 01 come t rineats and clean-uFoved ,. operations at t:"a Alpine mud theplant AlasY.afacility Andinto Gas ConservationuCoi tlisaict > operations WAS granted bY. .. ,The apptovoug 4lStQra f ARCOd. ttl > (AOGCC) to the 1, 1'7,; 1x99 letter from AOGCC to Dappt6Val wa 01: ARCO > Alaa)ca, inc., now Phillips Alaska. Tnc..,{PA7)-. > per peci,Y.ically' for. Alpine Uxil'J. 'Sita cDi and autiiorirea volumds up to > 35,000 barrels through the annularspace• > PAZ request that this aroval oeerationEoto `nr settinggsurfaceOperations condubtoY�lne. > Drill Site CD2- Cement- mixin£ p > wii7, be taking Place at the Guinn.and orlon torrro7.�c�rti"� gfithe icementing lin > aCtached to :Cha drilling :rig rank will have to be riinaed and the > of the conductor.'s, F.hs lines and mix -Mg into the annual > rinsate disPoHed of. PAI request nf. mixal to eratio o, -; riposte, and > other "clean-up from the mud And 1>ri,ne.mlxirig operations, > spare of approve w6lln located at Drill Sle CD2.. > questions pl'easc contact me at 670-4200, > i -f you haat any 4 > Tom Yansori > Alpiinne rield Environmental Compliance L::+�I tomJnauniiar:vcf PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-05 Rig: Doyon 19 Date: 5/16/2015 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: K. Harding /A. Dorr Pump used: #2 Mud Pump VStrokes ♦ 0.1000 Bbis/Strk 0.30 Bbl/min Type of Test: Casing Shoe Test LOT/FIT IVPumping down annulus and OP. Casing Test Pressure Integrity Test Hole Size: 12-1/4" `► Casing Shoe Depth JL Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 37. t 20 t-M 1 7.0 t-TVD 2044.0 Ft-MD2005.0 Ft-TV Strks psi Min psi Strks psi Min psi Casing Size and Description: 13-3/8" 68x/Ft L-80 RTC 'r 0 0 0 2600 0 20 0.00 890 assn Test Pressure IntegrltvTest -2-30 2600 1 50 __0_2T 880 Mud eight: M ud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight Estimates for Test: ppg Lb/100 Ft2 Lbs Mud Weight: Mud 10 min Gel: Rotating Weight: BlocksfTop Drive Weight: Desired PIT EMW: Estimates for Test: 9.4 ppg Lb/100 Ft2 Lbs Lbs ppg psi 0.9 bbis 4 30 2 2600 2 7 .50 ---870- 2.0 40 3 2 00 -3-120 1.0 88 25psi 92bbis �# 60000.0 8 50 4 2600 4 170 1.50 8-1 1 100 5 2580 5 220 2. 875 60Lbs 18.0 12 220 6 2560 6 27 .5 870 884 4 360 -7-756-0 -7-350 870 ► EMW-= ea o ressure+ u erg = +94 P 5 econci 0.052 x TVD �x 19977 / Shut-in Pressure, psi EMW at 2014 Ft-MD (1977 Ft-TVD) = 18.1 ppg 880 16 510 18 720 -20--870 8 2560 9 25 8 420 9 470 3.50 870 4.00 65 1 560 1 580_79U 865 22 1100 15 2560 11 640 5.00 860 a000 5 Lost 50 psi during test, 0 24 1260 20 2550 12 720 5.50 860 26 14701 25 25501 13 8001 6.00 855 28 15901 30 25501 14 8601 6.50 855 ssoo 30 1720 14.5 890 7.00 855 32 1900 7.50 850 34 2060 8.00 850 z000 36 2240 8.50 850 U.1 tr IF 38 2420 9.00 850 40 2600 9.50 85 10.00 &. 0 1500 w a 1000 Soo 0 0 1 1 2 3 4 tL ' Barrels L�(4 PrI itSING TEST .LEAK-0FFTEST 0 5 10 15 20 25 30 Shut-in time, Minutes o PIT Point Volume pum ed Volume Bled Back Volume Pum ed Volume Bled Back s S S 8 Comments: Tested casing with 9.9 DnlPlex mud 23:30 Hrs 5/16/18 Performed FIT with 9.4 LSND mud Summary qS/ a PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-05 Rig: Doyon 19 Date: 5/23/2018 Volume Input Volume/Stroke 0.1000'..ebis/Strk Pump Rate: Drilling Supervisor: A. Marushack -... Type of Test casing Siwe Test LOT/FIT / A. Dorr Pump used: #2 Mud Pum _ p •-.Strokes ♦ Pumping down annulus and DP. ♦ 0.50 Bbl/min Casing Test Pressure Integrity es Hole Size: Ba/a • Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 36.5 Ft 8921. F77_D 7125.0 Ft -TVD 6953. Ft -MD 7146.0 Ft -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: X9.5/a'4o#/FtL-80BTC •' 0 0 0 3100 0 0 0.00 1320 Casing Test PressurelntegritVTest 3 100 1 3100 2 40 0.25 1300 Mud Weight: 10.5 ppg Mud 10 min Gel: 12.0 Lb/100 Ft2 Test Pressure: 3000.0 psi Rotating Weight: Lbs Blocks/Top Drive Weight 60000.0 Lbs Estimates for Test: 7.8 bbls • Mud Weight: 10.5 ppg Mud 10 min Gel: 12,0 Lb/100 Ft2 Rotating Weight: Lbs Blocksrrop Drive Weight: 60000.0 Lbs Desired PIT EMW: 14.0 ppg Estimates for Test: 1315 psi 3.4 bbls • 6 175 -2-71-0-0 -4--70 0.50 130 9 250 3 3090 -6-180 1.00 1.50 2.00 1290 1. 1290 12 400 4 3090 8 280 15 500 5 3090 10 370 18 650 6 3050 12 450 2.50 1290 21 800 7 _37-0 14 540 3.00 1290 24 900 8 3050 16 640 3.50 1290 EMW = Ce-ak-off Pressure + Mud Weight= 1320 0.052 x TVD 0.052 x 7125 + 10.45 EMW at 8921 Ft -MD (7125 Ft -TVD) = 14.0 ppg PIT 15 Second Shut-in Pressure, 27 1050 9 3050 18 740 4.00 _117-90 30 71T57 10 3050 20 840 4.50 1290 1300 33 1300 15 30251 22 940 5.00 1290 3500 8 Lost 100 psi during test, h Id 96.8% f tet 36 14001 20 3000 24 10401 5.50 1290 39 1500 25 3000 26 1100 6.00 1290 �y++ , �� 42 1625 30 3000 28 1180 6.50 1290 3000 45 1750 30 1260 7.00 1290 46 1900 32 1320 7.50 1290 2500 51 2000 8.00 1285 54 2150 8.50 1285 U.11 57 2300 9.00 1285 = 2000 60 2400 9.50 11-7 10.00 1. U) w 26001 1 1 1 1 uj631 1500 2700 a � _ 2850 1000 3000 3100 N72 Soo 0 0 1 2 9 4 5 8 ] Barrels CASING TEST y- LEAK -OFF TEST 0 5 10 15 20 25 30 Shut -In time, Minutes o PIT Point Volume Pumped VolumerVolumeVolume Bled Back Pumped Bled Back 7.5 S S slbols Comments: Tested casing with 10.5 LSND mud 14:00 Hrs 5/23/18 Performed FIT with 10.45 ppg LSND mud 20:00 Hrs 5/23/18 I -8-05 hit -easing =-resrFiT-xisx ouuuiiaiy OA L0 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-05 Rig: I Doyon 19 Date: 5/.2212018 ............ . Drilling Supervisor: A. Marushack / A. Dorr Pump used: z Mud Pump _ Type of Test: 'Annulus Leak Off Test for Disposal Adequacy 'W 1 Pumping down annulus. W Volume Input Barrels ♦ 0.1000', BblslStrk ♦ Pump Rate: 0.30'lBbl/min Integrity es Casing Test Pressure Hole Size: 12-1j4. Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB CHF: 37.0 Ft2014.0 Ft -MD 19r i.0 Ft -TVD 7921.0 Ft -MD 641$.0 Ft -TVD - Bbls psi Min psi BbIs psi Min psi ----... Casing Size and Description: 13-3/8 68#/Ft L-80 BTC 0 0 0 0 0.00 380 Changes for Annular Adequacy Test Pressure IntegrityTest Enter outer casing shoe test results in comments Mud Weight:Ul Casing description references outer casing string. Inner casing OD:In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW:ppg Estimates for Test: EMW = Leak-o-ff Pressure + Mud Might= 577 + 10 5 0.052 x TVD 0.052 x 1977 EMW at 2014 FWD (1977 Ft -TVD) = 16.1 2 1 0.5 59 0.25 350 ppg 463 psi 0.8 bbls PIT 15 Secon Shut-in Pressure, psi 4 2 1 75 0.50 350 6 3 1.5 76 0 350 1.50 2.00 3b0 8 4 2 77 10 5 2.5 77 12 6 3 77 2.50 345 14 7 3.5 77 3.00 345 16 18 8 9 4 77 4.5 78 3.50 345 4.00 345 20 10 1 5 78 4.50 345 350 22 15 5.5 88 5.00 345 1000 Lu in soo Lu a 0 0 5 Shut o 24 20 6 133 5.50 345 26 25 6.5 203 6.00 345 28 30 7 277 6.50 345 30 7.5 335 7.00 345 32 8 390 7.50 345 34 8.6 455 8.00 345 36 9 511 8.50 345 38 9.5 577 9.00 345 40 10 428 9.50 ?� 10.00 IL 10.5 410 11 396 115 385 12 380 12.5 380 0 5 10 CASING 15 TEST 20 Barrels 25 30 -11--LEAK-OFF 35 40 TEST 45 10 -In PIT Point 15 time, 20 Minutes 25 30 Volume Pum ed Volume Bled Back Volume Pum edS Ws S S Comments: Pumped 12.5 bbls 10.5 ppg LSND for LOT, 300 bbls H2O water flush, 85 bbls diesel freeze protect. 13-3/8" Shoe FIT = 18.0 ppg on 5/17/18 Used Ball Mill injection pump #2 " iTao5A[ 11 avinrnary Cement Detail Report MT6-05 String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/11/201800:00 Cement Details Description Surface Casing Cement Cementing Start Date 5/14/2018 23:00 Cementing End Date 5/15/2018 02:38 Wellbore Name I MT6-05 Comment Cement Stages Stage # 1 Description Surface Casing Cement I Objective Top Depth (ftKB) Cement Surface Casing 36.5 Bottom Depth (ftKB) 2,014.5 Full Return? Yes Vol Cement... 169.0 Top Plug? Yes Bum Plug? Yes Q Pump Init (bbllm... 8 Q Pump Final (bbll... 3 Q Pump Avg (bbll... 8 P Pump Final (psi) 420.0 P Plug Bump 920.0 (psi) RecipT 1 Yes Stroke (ft) 120.00 Rotated? No I Pipe RPM (rpm) Tagged Depth (111(8) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 12 114 Comment 169 bbls good cement to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ft(B) 36.5 Est Btm (ftKB) 1,514.0 Amount (sacks) 1,044 Class LiteCRETE Volume Pumped (bbl) 357.0 Yield (fl'/sack) 1.92 Mix H2O Ratio (gal/sa... 6.88 Free Water (%) 1 Density (Iblgai) 1 11.00 Plastic Viscosity (CP) 258,000.0 Thickening Time (hr) 4.52 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fiuld Description Estimated Top (ftKB) 1,514.0 I Est Bim (ftKB) 2,014.5 Amount (sacks) 350 Class G Volume Pumped (bbl) 72.3 Yield (ft-Isack) 1.16 Mix H2O Ratio (gal/sa... 5.11 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) 145,000.0 Thickening Time (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 81112018 e, • - Cement Detail Report MT6-05 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/11/201800:00 Cement Details Description Intermediate Casing Cement Cementing Start Date 5/22/2018 04:30 Cementing End Date 5/22/2018 07:30 1 WellboreName MT6-05 Comment Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Isolate 9-5/8" Casing Shoe Top Depth (ftKB) 7,921.0 Bottom Depth (ftKB) 8,920.8 Full Return? Yes Vol Cement... Top Plug? Yes son Plug? Yes O Pump bit (bbllm... 8 IQ Pump Final (bbg... 3 O Pump Avg (bbl/... 8 P Pump Final (psi) 530.0 P Plug Bump (psi) Reclp7 Yes .stroke In) Rotated? 7.00 No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill 183/4 Out Diameter (in) Comment Did not bump plug, floats held. CIP = 7:21 Hrs Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid DescriptionEstimated Top(ftKB) 7,921.0 Est sen (Ii 8,421.0 Amount(sacks) 104 Class Volume G 42.7 Pumped(bbl) Yield (ft -/sack) 2.31 Mix K20 Ratio (sidles... 13.09 Free Water I%) Density (Iblgal) 12.20 Plastic Viscosity (cP) 47,000.0 Thickening Time (hr) CmprStr 8.00 1 (psi) Additives Additive Type Concentration Cork; Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,421.0 Est Btm (ftKB) 8,920.9 Amount (sacks) 241 Class Volume C 49.8 Pumped (bbl) Yield (ftVsack) 1.16 Mix H2O Ratio (gallsa... 5.08 Free Water I%) Density (Ib/gal) 15.80 138,000.0 Plastic Viscosity (cP) Thickening Time (hr) Chi1 4.45 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 8/1/2018 Security Level: AK Development AL Daily Drilling Report (No Costs) MT6-05 Report Number: 4 Report Date: 5114/2018 Rig: DOYON 19 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftK6) End Depth (ftKB) MT6-05 Development 2.45 4.0 .0.00 2,024.0 2,024.0 Actual Stan Date Original Spud Date I AFE our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/11/2018 5/12/2018 166.24 66.37 -0.13 7/162018 Last casing string SURFACE, 2,014.5ftKB Ops and Depth @ Morning Report 24hr Forecast RID After Cmnt Job Cement casing. RID cementers. NID diverter. NN BOPE & test. Last 24hr Summary RIH 13-3/8" csg & land on hanger @ 2,014'. Circ & cond mud for cement job. Pump cement as per SLB. General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on high line MT6. Patchy Fog, 29°F, Wind E @ 7 mph, Vis 10-m .56.0 Supervisor Toe Rick Bjorhus,Rig Supervisor" Rig Supervisor Adam Dorr,Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Weifeng Dai,Dnlling Engineer - Drilling Engineer Hanna Sylte,Completions Engineer Completions Engineer Time Log Time Start Time ErALme Dur(hn Phase Op code Actity Co. -bX Trot Code Tlhi Class Start Depih(ftK8) End Depih(ftKet Operation 00:00 00:45 0.75 SURFAC CASING RURD P 0.0 0.0 RN strap tongs & finish R/U for casing. 00:45 12:15 11.50 SURFAC CASING PUTB P 0.0 1,306.0 PJSM on casing. RIH 13-3/8" 68# L-80 TXP casing to 1306'. MN shoe track & check floats (good). (Having an issue with alignment & galling threads on casing had to swap out several jts casing). 12:15 13:30 1.25 SURFAC CASING CIRC P 1,306.0 1,306.0 Circ & cond mud. Stage pumps 1 up to 5 bpm / 90 psi. PU wt 128 k/SO wt 124 it 13:30 1700 3.50 SURFAC CASING PUTS P 1,306.0 1,937.0 Cont. to RIH 13-3/8" 68# L-80 TXP casing f/1306 to 1937'. 1700 18:00 1.00 SURFAC CASING HOBO P 1,937.0 2,014.0 M/U hanger & landing jt. Land Casing on hanger @ 2,014.5' 1800 21:00 3.00 SURFAC CEMENT CIRC P 2,014.0 2,014.0 Circ&condmudforcement job. Stage pumps up to 8 bpm 1120 psi. Reciprocate pipe. PU wt 175 k/SO wt 155k 21:00 21:45 0.75 SURFAC CEMENT RURD P 2,014.0 2,014.0 RID casing bales. B/D top drive. R/U cement lines to Volant. 21:45 23:00 1.25 SURFAC CEMENT CIRC P 2,014.0 2,014.0 Cont. to circ 8 cond mud for cement job thru cement linesw/ 8 bpm 1350 psi. Reciprocate pipe. PU wt 180 k/SO wt 174 k. SIMOPS -work on 1-12S sensor in pits. 23:00 00:00 1.00 SURFAC CEMENT CMNT P 2,014.0 2,014.0 PJSM on cementing. Rig load 50 bbls nut plug marker in pipe. Dowell pump 1.2 bbls H2O & PT to 2500 psi (good). Dowell pump 100 bbls 10.3 ppg mud push w/4 bpm 1100 psi. Shut down & drop bottom plug. Mud Check Data YPC Del (10.) Gel(10m) Gel (30m) HTHP FjAraie Oensay Temp Solids. Corr. Type Dep(We) Densoimai) Vls(s/gq PVCak(cP) (Ibvloaic ) (lbulcot) (Indio ') (Ibfl100fn) MBT(kA" (MLI M) pH DRILPLEX 2,024.0 9.85 19.0 19.0 13.0 27.0 31.013 19.0 0.0 10.9 55.0 10.8 DRILPLEX 2,024.0 9.85 14.0 29.0 25.0 27.0 29.012 19.0 0.0 10.9 58.0 10.8 DRILPLEX 2,024.0 9.85 15.0 28.0 26.0 33.0 34.014 19.0 0.0 10.9 56.0 10.8 Latest BOP Test Data Dee Dem Page 1/2 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-O5 �,. Report Number: 4 Rig: DOYON 19 Report Date: 5/14/2018 Mud Check Data Type Dept(MKS) Dans(lblgali v.(s/np PVicek(op) YPCak (Ibfl100w) Gel(Os) OvIloofe) Gel(10m) I (IbfI100R'} Gel (30;1 {pillo0a� MBT(ioezl) HTHPFObate (mLC3gnin) pH Density Temp (`F) Solids, C. (%} DRILPLEX 2,024.0 9.85 13.0 28.0 23.0 30.0 1 33.014 20.0 0.0 10.6 74.0 10.8 Injection Fluid Fund I Soorce From Lease(bbn Dest V.r . Manilest Number Note Drilling Mud WBM Drilling Mud WBM MT6-05 MT6-05 275.0 275.0 CD1-01 CD1-01 AES AES 529571 529570 1 MT6-05 Source Well MT6-05 Source Well Wellbores Wellbore Name MT6-05 Wellbore APVUWl 501032077100 Secfion Des Size (in) Act Top (fiKB)Act BM (WB) Siad Date End Date COND1 SURFAC INTRMi INTRM2 PROD1 42 16 121/4 83/4 6 36.5 115.0 2,024.0. 8,933.0 11.,119.0 115.0 2,024.0 8,933.0 11,225.0 17,391.0 2/6/2018 5/12/2018 5/172018 5232018 6/182018 2/6/2018 5/1712018 5/2312018 6/2/2018 6/30/2018 Casing Strings Csg Des Run Date 00(m) 1W en (lbin) Grade I Set Depth, (ftKB) I Com SURFACE 5/14/2018 1 133181 68.00 1 L-80 1 2,014.5 115 Centek & 34 Bow Spring Cement Surface Casing Cement - Started @ 5/14/2018 TypeWellbore Casing MT6-05 Cemented String SURFACE, 2,014.5ftKB Cement Evaluation Results 169 bbls 11.0 ppg cmnt to surface. CIP @ 2:38 Hrs 5/15/18 Sig # 1 Description Surface Casing Cement Top Depth (ftKB) 36.5 Bottom Depth (ftKB) Q Pump Final... 2,014.5 3 P Pump Final (psi) 420.0 Fluid ICless. Amount (sacks) Vol Pumped (bbl) Dens f.k(M(eack) I Eat TOP(MB) Est Bt. (ftB) Lead Cement Tail Cement LiteCRETE G 1,044 350 357.0 72.3 11.001.92 15.80 1.16 36.5 1,514.0 1,514.0 2,014.5 Page 2/2 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 Report Number: 5 Rig: DOYON 19 Report Date: 5/1512018 Wellbore Well Type DFS (days) DOL (days) Depth Progress In) Start Depth (ftKe) End Depth (ftKB) MT6-05 Development 3.45 5.0 0.00 2,024.0 2,024.0 Actual Start Date Original Spud Date APE Our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/1112018 5/1212019 66.24 66.37 -0.13 7/16/2018 Last Casing String SURFACE, 2,014.5ftKB Ops and Depth @ Morning Report 24hr Forecast Test BOPE Test ROPE. M/U 12.25" BHA#2. RIH. Test casing. Drill out. FIT. Drill ahead. Last 24hr Summary Cont. to pump cement. Bump pig, check floats (good). Flush stack & R/D casing/cementing tools & equipment. N/D diverter system. N/U BOPE. N/U MPD. General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on high line MT6. Tested gas alarms Overcast, 24°F, Wind E @ 14 mph, Vis 10 m I 56.0 Supervisor Title Ken Hardin ig Supervisor Rig Supervisor Adam Dor,Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Wefiang Dai,Drilling Engineer Drilling Engineer Hanna Sylte,Completions Engineer Completions Engineer Time Log Sart Tme End Tme Dur(hr) Phase Cp Cpde Activity Cade Time -T-x TrUCode Trbl Class Sart Depth(ftKa) End DepmfftK8) Operatoo 00:00 02:45 2.75 SURFAC CEMENT CMNT P 2,014.0 2,014.0 Dowell pump 357 bible 11.0 ppg 1.92 ft3/sx yield UteCRETE lead cement, 72.3 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20.1 bbis H2O. Rig displace w/268.7 bbls / 2692 stks 10.0 ppg DrillPlex w/8 bpm 1650 psi. At 250 bbls slow pumps to 3 bpm / 420 psi. Bump plug, pressure 500 psi over to 920 psi for 5 min. Check floats / F/C good. CUP @ 2:38 Hrs. 0245 0330 0.75 SURFAC CEMENT WWWH P 0.0 0.0 Disconnect lines to knife valve. Flush riser, function diverter annular and flush again 3X w/biack H2O. 03:30 05:00 1.50 SURFAC CEMENT RURD P 0.0 0.0 R/D cement lines. B/D same. R/D voiant & LID same. B/O landing It & UD same. L/D 90' mouse hole. 05:00 12:00 7.00 SURFAC CEMENT NUND P 0.0 0.0 Remove hole fill & bleeder lines. Drain lines. Disconnect Koomy lines. N/D riser. N/D diverter annular & knife valve. N/D diverter line. Remove barricade. 12:00 13:45 1.75 SURFAC WHDBOP NUND P 0.0 0.0 N/U well head & test void V1000 psi f/10 min good. SIMOPS cont, to remove diverter line sections from back of pad. 13:45 19:45 6.00 SURFAC WHDBOP NUND P 0.0 0.0 N/U BOPE. Tighten speed head. N/U choke & kill lines under rig floor. Tighten BOPE rams doors. SIMOPS - Test gas alarms. MN rocket launcher. 1945 0000 4.25 SURFAC WHOBOP MPDA P 0.0 0.0 M/U MPD equipment. N/U MPD clamp, orbit valve, flow box, trip nipple, Katch Kan, & 1502 lines. SIMOPS - grease choke, clean pits, install 90' mouse hole. P/U test jt & MN test plug. Latest BOP Test Data Date it com Page 112 Report Printed: 9111/2018 Security Level: AK Development Daily Drilling Report (No Costs) } MT6-05 =�'Rig: Report Number: 5 DOYON 19 Report Date: 5/15/2018 Mud Check Data YP CA. Gal (10a) Gal (10.) Gel (M.) HTHPFilbate Density Temp Solids,C. TYPe Depm(MB) Dans(Polgar) Ms(s/gt) PVCabtP) (Ibr/10DM) Ow/10M (IbN1oaftl) (0*100" MU(DiDbO (mU90min) pH (°F) M DRILPLEX 2,024.0 9.80 19.0 21.0 13.0 18.0 21.009 16.0 0.0 11.0 48.0 10.0 DRILPLEX 2,024.0 9.80 %0 20.0 13.0 18.0 21.009 16.0 0.0 11.0 50.0 10.0 DRILPLEX 2,024.0 9.80 19.0 20.0 13.0 18.0 21.009 16.0 0.0 11.0 50.0 10.0 DRILPLEX 2,024.0 9.85 19.0 18.0 13.0 27.0 31.013 19.0 0.0 10.9 55.0 10.8 Injection Fluid FW Source From Lease (bbg Dead Vendor Manifest Number Moro Cementing Fluids MT6-05 275.0 CDI-01 AES 529573 MT6-05 Source Well Cementing Fluids MT6-05 275.0 CDI-01 AES 529572 MT6-05 Source Well Cementing Fluids MT6-05 275.0 CDI-01 AES 529574 MT6-05 Source Well Cementing Fluids MT6-05 275.0 JCDI.01 AES 529575 MT6-05 Source Well Drilling Mud WBM MT6-05 275.0 CDI-01 AES 529576 MT6-05 Source Well Wellbores Wellbore Name Wellbore API/UNI MT6-05 501032077100 Section Des Size(in) Aa Top(WB) Act Btm(eKB) Stan Data End Date COND1 42 36.5 115.0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,024.0 5/12/2018 5/1712018 INTRMi 121/4 2,024.0 8,933.0 5/17/2018 5/23/2018 INTRM2 83/4 8,933.0 11,225.0 5/23/2018 6/2/2018 PROD1 6 11,119.0 17,391.0 6/18/2018 6/30/2018 Page 212 ReportPrinted: 911112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-O5 /// Report Number: 10 Rig: DOYON 19 Report Date: 5/2012018 Wellbore Well Type DFS (days) DOL (days)Depth Progress In) Start Depth (fti End Depth (ftKB) MT6-05 Development 8.45 10.0 0.00 8,933.0 8,933.0 Actual Start Date Original Spud Date AFE Our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/11/2018 5/12/2018 66.24 64.87 1 1.37 7/14/2018 Last Casing String SURFACE, 2,014.5ftKB Ops and Depth @ Morning Report 24hr Forecast RIH 9-518" Call 3,500' Cont. to run 9-5/8" casing and land on hanger @ 8,923.20. Circ & Gond for cement job. Cement casing as per Si Last 24hr Summary Circ & Cond for trip out. F/C (static). Strip OOH to 4,863'. Pull RCD & install trip nipple. Circ B/U. POOH to 1,939'. Circ B/U. POOH & L/D BHA #2. C/O top pipe rams & test same. RAJ to run casing. RIH 9-5/8" casing to 485' General RemarksWeather Head Count No AIS. Camp on High Line @ CD5. Rig on high line MT6. Overcast, 26'F, Wind NE @ 21 mph, Vis 10 m 57.0 Supervisor Ttle Andy Maruehack,Drilling Engineer Drilling Engineer Adam Dorc, Rig Supervisor Rig Supervisor Diana Guzman.Rig Engineer Rig Engineer Weifeng Dai, Drilling Engineer Drilling Engineer Hanna Sylte,Complehons Engineer Completions Engineer Time Log TmeP Siar Tme End rime Dur mn Pnase OP Code Atii Cpde -T-X Tbl Cotle Tt4 Cass Start DepN (aKB) End pepN (aKBI Ope ation 00:00 02:45 2.75 INTRMI CASING CIRC P 8,819.0 8,629.0 Cont to circ hole clean for 6+ BILI total w/900 gpm 13500 -3320 psi, 170 - 150 rpm / 10 k trq. Pumped nut plug sweep after 5th B/U. Racked back 2 stands to 8,629' 02:45 03:00 0.25 INTRMI CASING OWFF P 8,629.0 8,629.0 F/C (static). SIMOPS- lineup MPD equipment to strip OOH 03:00 06:15 3.25 INTRMI CASING SMPD P 8,629.0 4,863.0 Strip OOH as per MPD schedule 114,863'. 4,863'. Few tight spots, worked thru once and clear. 06:15 0630 0.25 INTRMI CASING OWFF P 4,863.0 4,863.0 F/C (static). SIMOPS- PJSM on removing RCD bearing 06:30 0700 0.50 INTRMI CASING MPDA P 4,863.0 4,863.0 Pull RCD bearing & install trip nipple. 07:00 07:30 0.50 INTRMI CASING CIRC P 4,863.0 4,771.0 Circ B/U w/900 gpm 12760 psi, 180 rpm 17 k trq. Rack back 1 stand f/4,863'to 4,771' 07:30 10:30 3.00 INTRMI CASING TRIP P 4,771.0 1,939.0 POOH f/4,771'to 1,939'. Few tight spots, worked thru once and Gear. 10:30 11:00 0.50 INTRMI CASING CIRC P 1,939.0 1,845.0 Pump 30 bbl sweep & cim clean w/900 gpm / 2100 psi, 120 rpm / 3 k trq. Rack back 1 stand f/1,939' to 1,845' 11:00 11:30 0.50 INTRMI CASING OWFF P 1,845.0 1,845.0 FIC (static) 11:30 12:15 0.75 INTRMI CASING TRIP P 1,845.0 622.0 POOH f/1,846to 622' 12:15 12:30 0.25 INTRMI CASING OWFF P 622.0 622.0 FIG(static) 12:30 14:45 2.25 INTRMI CASING BHAH P 622.0 0.0 Rack back HWDP &jars & UD BHA as per Baker reps f/622' to surface. Bit Grade: 2-1-CT-G-X-1- LT-TD 14:45 1545 1.00 INTRMI CASING BHAH P 0.0 0.0 Clean& clear floor of BHA tools& equipment 15:45 16:30 0.75 INTRMI CASING WWWH P 0.0 0.0 MN stack washer to single jt& flush stack. Functioned rams & flush again. Latest BOP Test Data Dide Com 1,11W2018 160 ROPF �IqQMQO to[ b/10 Mirlt; W/,9 teSt in nts Annular 4" nemco Choke va[VPq 1 14 IRQP's choke needle valyp Urinpr/low Page 1/3 Report Printed: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 Report Number: 10 Report Date: 5/20/2018 Rig: DOYON 19 Time Log TmeP SoTime rt End Tune Dur(hr) Phase Op Cade Activity Cafe -T-x Tral Code Tral Class start Depth (i Ertl Depth(Iti Operattan 16:30 18:30 2.00 INTRMI CASING BOPE P 0.0 0.0 Pull wear ring & set test plug. C/O upper rams to 9-5/8" solid body. R/U testing equipment. SIMOPS - R/U Volant 1.8:30 20:00 1.50 INTRMI CASING BOPE P 0.0 0.0 Test w/9-5/8" test jt. Annular 250 psi for 5 min, 2500 psi for 10 min. Upper rams 250 psi for 5 min, 3500 psi for 10 min. 20:00 20:30 0.50 INTRMI CASING BOPE P 0.0 0.0 R/D testing equipment Pull at plug & set thin wall Casing 13- 3/16" rasing wear bushing. 20:30 22:00 1.50 INTRMI CASING RURD P 0.0 0.0 R/U casing tools & equipment. Install mud saver on Volant 2200 00:00 2.00 INTRMI CASING PUTS P 0.0 485.0 PJSM on running casing. M/U shoe track & check floats (good). RIH w/9-5/8" TN -80 40# TXP-HS casing to 485' Mud Check Data W Oak Gel (test Gal (1w Get (War) HTHP Fileate Density Temp Salids. Cort. Type Depth(ttKm Dens(lalgaf Ms(Vgt) PV Cak(cP) OW10M'I ( HOOtm (@010011') (IOf1100M9 MST(hi (ntwftin) pH ('F) (%) Low Solids 8,933.0 10.50 44 11.0 24.0 12.0 16.0 20.008 18.5 0.0 9.5 82.0 13.3 Non - Dispersed Low Solids 8,933.0 10.50 44 11.0 25.0 12.0 17.0 20.008 18.5 0.0 9.5 84.0 13.3 Non - Dispersed Low Solids 8,933.0 10.50 42 11.0 25.0 12.0 17.0 20.008 18.5 O.O 9.5 88.0 13.3 Non - Dispersed Low Solids 8,933.0 10.50 41 11.0 25.0 12.0 17.0 20.008 18.5 0.0 9.6 109.0 13.3 Non - Dispersed Injection Fluid Fluid source I From Lease (pan Deet Vendor 1 Marilest Number Note Drilling Mud WBM 11VIT6-05 1 265.0 CD1-01 JAES 1529597 MT6-05 Source Well Drill Strings: BHA No. 2 - 12-114" AutoTrack BHA / Bit Run No. 2RR - 12 1/4in, DD605SX, 5281206 Depth In (fti Depth Out (ftKB) TFA (incl Noz) (W) Noules (1/J2") IARC Bit Dull String Wt (1000Ihfl 2,024.0 8,933.0 1.02 12112112 5/15115 2 -1 -CT -G -X -O -LT -TD 206 Drill String Components its Mem Des OD Oil ID (in) Tap Coon Sz (M) Top Thread Cum Len(ft) AutoTrak Steering head 11.86 2.48 9 12 T2 9.47 Flex sub w/Stab 12114 3.12 91/2 T2 21.35 NM X/O sub 9112 3.50 81/4 T2 24.37 OnTrak - MWD 8114 2.75 81/4 T2 42.77 Mod stab 121/4 2.88 81/4 T2 46.91 BCPM 8114 2.88 8114 T2 58.58 Stop sub 81/4 3.13 6 518 Reg 60.22 Filter 8 3.00 6 518 Reg 63.23 Float 8 3.00 65/8 Reg 66.34 Float 8 3.00 6 518 Reg 68.19 Float 8 3.00 6 518 Reg 70.10 3 NMDC 8 2.75 6 518 Reg 159.32 )VO sub 8 2.75 41/2 IF 162.72 12 HWDP 5 3.00 412 IF 531.94 Jars 6.258 2.75 4121F 561.62 2 HWDP 5 3.00 4112 IF 622.35 Page 213 Report Printed: 9/1112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 Report Number: 10 Report Date: 5/2012018 Rig: DOYON 19 Drill String Components dts Itam Uas I On (in) ID (in) Top Conn Sz(in) I Tap Thread Cum Len (ft) 118 Drill Pipe 5 4281 4 11211F 4,328.50 Reamer 105/8 2.75 41/2 IF 4,335.62 146 Drill Pipe 5 4.28 4 1/2 IF 8,933.00 Drilling Parameters Ila, Sart Depth Ertl Depth SlitluB (4Pm) WOB RPM PU Src VvI Dnp Strutt SO Sb Wt (flKB) (ftK8) Cum Deptlr (fl} Cum DMITme (hp Tme(N) (gPm) (10001Pq (rpm) SPP (ps) (100p1ht) (1eWIbQ (t00p1E� OReun Tq Dre Tq 8,933.0 8,933.0 6,909.00 40.10 Wellboms Wellbore Name Wellbore APIIUWI MT6-05 501032077100 Section Des Site(in) Act Top(f B) Act Btm(WB) Start Date End Date COND1 42 36.5 115.0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,024.0 5!12/2018 5/17/1018 INTRMI 121/4 2.024.0 8,933.0 5/1712018 5/23/2018 INTRM2 83/4 8,933.0 11225.0 5/13/2018 6/2/2018 PROOI 6 11,119.0 17,391,0 6/1812018 6/30/2018 Page 313 ReportPrinted: 911112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 ReportNumber: 11 Report Date: 5/2112018 Rig: DOYON 19 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft)Start Depth (ftKB) End Depth (ftKB) MT6-05 Development 9.45 11.0 0.00 8,933.0 18,933.0 Actual Start Date 1 Original Spud Date 1AFE our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/11/2018 5/12/2018 166.24 65.37 10,87 7/15/2018 Last Casing String INTERMEDIATE #1, 8,920.8ftKB Ops and Depth @ Morning Report 24hr Forecast Cementing Circ & cond for cement job. Cement casing as per SLB. Install pack off. Install 7" spool. C/O upper pipe rams. MIU BHA #3. Last 24hr Summary RIH 9-5/8" f/485' to 4,017'. C&C. RIH 9-5/8" casing f/4,017'to 5,476'. C&C. RIH 9-5/8" casing f/5,476' to 6,361'. C&C. RIH 9-5/8" casing f/6,361' to 7,669'. C&C. RIH 9-5/8" casing f/7,669' & land on hanger @ 8,920.8'. Circ & cond for cement job. General Remarks Weather Read Count No AIS. Camp on High Line @ CD5. Rig on high line MT6. Overcast, 29`F, Wind NE @ 16 mph, Vis 10 m 57.0 Superv,sor Title Andy Manrshaek,DrillingEngineer Dnlling Engineer Adam Don-,Rig Supervisor - Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Weifeng Dai,Drilling Engineer Drilling Engineer Hanna Sylte,Completions Engineer Completions Engineer Time Log Time SumiTme Erd Tema Dur(hn Phase Op Code Arbvity Code -T-% Trd Code TNI Class start Depth(AKB), End Depth (WS) dpemoori 0000 06:00 6.00 INTRMI CASING PUTB P 485.0 4,017.0 RIH w/9-5/8" f/485' to 4.017'. PU wt 180 k/SO wt 155k 06:00 06:30 0.50 INTRMI CASING RURD T Non-ng Other 4,017.0 4,017.0 C/O cup on Volant tool Surface Eqp 06:30 08:00 1.50 fNTRMl CASING CIRC P 4,017.0 4,017.0 Circ & cond un-even mud wts w/6 bpm / 200 psi. Max mud wt observed 11.0 ppg. 08:00 10:15 2.25 INTRMI CASING PUTB P 4,017.0 5,476.0 RIHw/9-5/8"f/4.017'to5,476'. PU wt 175 k/SO wt 145k 1015 11:15 1.00 INTRMI CASING CIRC P 5,476.0 5,476.0 Circ & cond un-even mud wts w/8 bpm / 320 psi. Max mud wt observed 11.2 ppg. 11:15 13:15 2.00 INTRMI CASING PUTB P 5,476.0 6,361.0 RIH WS-5/8" f/5,476' to 6,361'. PU wt 240k/SO wt 195k 13:15 14:15 1.00 INTRMI CASING CIRC P 6,361.0 6,361.0 Break circ w/5 bpm / 480 psi 1415 1700 2.75 INTRMI CASING PUTB P 6,361.0 7,669.0 RIH w/9-5/8" f/6,361'to 7,669'. PU wt 310 k/SO wt 195 k. (Cross threaded 2 jts of casing. C/O bad jts.) 17:00 20:00 3.00 INTRMI CASING CIRC P 7,669.0 709.0 Circ & cond un-even mud wts w/8 bpm / 520 psi. Max mud wt observed 12+ ppg. Added water & ran centrifuge to condition to 10.5 ppg In / 10.7 ppg Out 20:00 22:30 2.50 INTRMI CASING PUTB P 7,669.0 8,883,0 RIH W/9-5/8" V7,669'to 8,883". PU wt 370 k 7 SO wt 220 k 2230 23:00 0.50 INTRMI CASING HOSO P 8,883.0 8,920.0 M/U hanger & landing jL Wash down w/1 bpm & land casing on hanger @ 8, 920.86' 23:00 00:00 1.00 INTRMI CEMENT CIRC P 8,920.0 8,920.0 Circ &wind mud for cement job. Stage pumps to 5.5 bpm / 530 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. Max mud wt out observed 11.1 ppg Latest BOP Test Data Date Com 13/1011217)118 it Test BOPE 250/3500 for 5110 rn nIq w/5 test ioiats. Annular 4" nemen Choke yAlyaq 1 14 IROP's rhnkp npedle, valve Unnaolow Page 112 ReportPrinted: 9/1112018 Security Level: AK Development AL i Daily Drilling Report (No Costs) MT6-05 ReportNumber: 11 Rig: DOYON 19 Report Date: 5/21/2018 Mud Check Data YP C.I. Gel (t Os7 Gel(lm) Gel(30m) HTHPFilVate Density Temp Solas, Corr Type Dept(eKS) Dens (Iblgal) Hs(./q0 PVCak(cP) (Ibf/100ft•) (lbf/t00n Qbf/100111 (lvile0R') MBT(lbtbbp (mU30min) pH (°F) (%) Low Solids 8,933.0 10.50 50 11.0 29.0 11.0 15.0 20.008 24.5 0.0 9.6 80.0 13.8 Non - Dispersed Low Solids 8,933.0 10.55 46 11.0 26.0 12.0 16.0 21.009 18.0 0.0 9.5 80.0 13.5 Non - Dispersed Low Solids 8,933.0 10.50 46 11.0 26.0 12.0 16.0 21.009 18.0 0.0 9.8 82.0 13.3 Non - Dispersed Low Solids 8,933.0 10.50 48 11.0 26.0 11.0 16.0 20.008 18.5 0.0 9.6 75.0 13.3 Non - Dispersed Injection Fluid Fluid Source From Lease(bbQ Dest I Vendor Manifest Number Note Drilling Mud WBM M16-05 265.0 CL)1-01 I AES 1529598 1 MT6-05 Source Well Wellbores Wellbore Name Wellbore APIIIIWI MT6-05 501032077100 Sedipn Des Slze (in) Act Top (ftKH) Act Bnn(ftKB) start Date End Date COND1 42 36.5 115.0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,024.0 5/12/2018 5/1712018 INTRMI 121/4 2,024.0 8,933.0 5/17/2018 5/23/2018 INTRM2 83/4 8,933.0 11,225.0 5/23/2018 6/2/2018 PROD1 6 11,119.0 17,391.0 6/18/2018 6/30/2018 Casing Strings Csg Des Run Date OD (in) Wf en (Ib/ft) Grade I Set Dept (ftKB) Com INTERMEDIATE#1 5/21/2018 95/8 40.00 L-80 8,920.8 39 = 12-1/4" Centeks 1 1 23 = 13-3/8" Bow Spring Page 212 ReportPrinted: 911112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 Report Number: 12 Rig: DOYON 19 Report Date: 5/22/2018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKB) End Depth (ftKB) MT6-05 Development 10.45 12.0 0.00 8,933.0 8,933.0 Actual Start Date 1 Original Spud Date AFE Our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 5/11/2018 5/12/2018 166.24 65.37 0.87 7/15/2018 Last Casing String INTERMEDIATE #1, 8,920.8ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE Test BOPE. M/U BHA#3. RIH to float equipment Test rasing. Slip & cut dell line. Drill out shoe track. FIT. Drill rat hole. Last 24hr Summary Circ & cond for cement job. Cement casing as per SLB. Install pack off. N/D BOPE. Install 7" spool. N/U BOPE. C/O upper pipe rams. R/U to test. R/U to AD LOT. Test BOPE. General Remarks Weather Heatl Count No AIS. Camp on High Line @ CD5. Rig on high line MT6. Tested gas alarms Overcast, 28°F, Wind NE @ 18 mph, Vis 10 m 60.0 Superv¢ar TW. Andy Marushack,Dhiling Engineer Drilling Engineer Adam Dorr,Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer eifeng Dai,Drdling Engineer Drilling Engineer Hanna Sylte,Completons Engineer Completions Engineer Time Log TmeP Start Tine Entl Time Dur(hr) Pnese Op Cade ActMtyOxie -T.X TrbFcode Tbi class StartDehin IWB) End DWM(WB) Operation 00:00 03:30 3.50 INTRMI CEMENT CIRC P 8,920.0 8,920.0 Circ& cond mud for cement job. Stage pumps F/5.5 to 8 bpm / ICP 530 psi / FCP 400 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. 03:30 04:00 0.50 INTRMI CEMENT RURD P 8,920.0 8,920.0 RID mud saver. B/D top drive. R/U cement lines. 04:00 04:30 0.50 INTRMI CEMENT CIRC P 8,920.0 8,920.0 Break circ thru cementing lines w/8 bpm 1590 psi. PJSM on cementing. 04:30 07:30 3.00 INTRMI CEMENT CMNT P 8,920.0 8,920.0 Dowell pump 1.5 bible H2O & PT lines to 4000 psi (good). Dowell pump 60 bible 12.0 ppg mud push, drop bottom plug, 42.7 bbls 12.2 ppg 2.31 ft3/sx yield G class lead cement, 49.8 this 15.8 ppg 1.16 ft3/sx yield G class tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace w/653 bbis / 6543 stks 10.5 ppg LSND w/8 bpm 1820 psi. At 640 bbls slow pumps to 3 bpm / 530 psi. Did not bump plug, Check floats & slight weeping. CIP @ 7:21 Hls. 07:30 08:00 0.50 1NTRM1 CEMENT OWFF P &0 0.0 Install gauge on Volant & stab into landing it FIG for 30 min. Floats holding. Well static. SIMOPS - RID cementing lines 08:00 09:45 1.75 INTRMI CEMENT RURD P 0.0 0.0 RID Volant & back out landing jt. LID 90' mouse hole. Open IBOP's on top drive & B/D. SIMOPS - Prep to N/D BOPE. N/D MPD equipment. RID Katch Kan & hole fill lines. 0945 11-.00 1.25 INTRMI CEMENT WWSP P 0.0 0.0 FMC pull wear ring. Install pack 1 off & test 5000 psi (good). Latest BOP Test Data Dale Com i1Te9t S/161217118 ROPF 96(71135[710 for �110 ni w/5 test joint% Annular 4" nernm Choke valvem 1 14 IROP-q Choke neprie valve Unnernow Page 1/3 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-05 ft -Rig: Report Number: 12 DOYON 19 Report Date: 5/22/2018 Time Log Time P Start Time End Time Durain Plume op Cada Activity Cade •T.X Trbl Code Trbl Class Start DePd1(IIKa) End Depm(aKS) Operation 11:00 13:45 2.75 INTRMI CEMENT NUND P 0.0 0.0 Pull trip nipple & R/D flow line. Loosen studs on well head. L/D flow box. PN & move BOPE away from well head. 1.3:45 15:15 1.50 INTRMI CEMENT NUND P 0.0 0.0 FMC N/U 7" casing spool. Set BOPE back on well head. Torque lower flange & test void to 5000 psi / 15 min (good). Torque upper spool to ROPE. 15:15 16:15 1.00 INTRMI CEMENT BOPE P 0.0 0.0 C/O upper rams to 4-1/2" X 7" VBR's 16:15 18:45 2.50 INTRMI CEMENT MPDA P 0.0 0.0 Install flow box. NIU MPD equipment Install trip nipple. 1845 23:15 4.50 INTRMI WHDBOP RURD P 0.0 0.0 Install mouse hole. RN to test ROPE. Fill stack w/1-120 & flood lines. Check for leaks. H2O leaking out of MPD trip nipple clamp. Truoble shoot. Decision made to BOPE test without trip nipple. Perform BOPE shell test (good). RN ball mill to AD LOT. Attempt to PT ball mill lines and having trouble with pumnps. Trouble shoot pumnps. PTY to 2500 psi good. 23:15 00:00 0.75 INTRMI WHDBOP BOPS P 0.0 0.0 Begin BOPE test w/5" test it 1 Tested gas alarms. SIMOPS-AD LOT on 13-3/8" X 9-518" annulus. Mud Check Data YP Cak Get (10s) Gal (lam) Gat (30m) HTHPFftate DensityTemp Solid%Cam. Type Dept (ftKB) Denspblgap Vu(s/qq PVCald(cP) Qbtl100" (11,610011') (W1100" (Wilm11'1 MST(iblbbp (mLMOmin) pH (IF) (%) Low Solids 8,933.0 10.60 46 11.0 24.0 9.0 12.0 15.006 21.0 0.0 9.5 75.0 13.8 Non - Dispersed Low Solids 8,933.0 10.60 45 11.0 24.0 10.0 12.0 15.006 21.0 0.0 9.5 78.0 13.8 Non - Dispersed Low Solids 8,933.0 10.50 43 11.0 23.0 11.0 15.0 16.007 23.0 0.0 9.6 82.0 13.8 Non - Dispersed Low Solids 8,933.0 10.50 42 11.0 22.0 8.0 12.0 16.007 24.0 0.0 9.4 88.0 13.8 Non - Dispersed Injection Fluid FhrM Source From Lease (bit Dest I Ventlm I Manifest Number I Not. Diesel MT6-OS 85.0 MT6-05 Freeze Protect OA Drilling Mud WBM Drilling MT 12.5 MT6-05 AD LOT on OA Fresh Water MT6-05 300.0 MT6-05 H2O Flush Wellbores Wellbore Name Wellbore API/UWI MT6-05 501032077100 Seotian Dm sve (m) Aa Top (ftKB) Act BM (XKB) Stan Date End Date COND1 42 36.5 115.0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,024.0 5/122018 5/172018 INTRMI 121/4 2,024.0 8.933.0 5/172018 5/232018 INTRM2 8314 8,933.0 11,225.0 5/232018 6122018 PROD1 6 11,119.0 17,391.0 6/182018 6/302018 Page 213 Report Printed: 9/112018 Security Level: AK Development AL Daily Drilling Report (No Costs) a�Fx, 4 MT6-05 Report Number: 12 Report Date: 5122/2018 Rig: DOYON 19 Cement Intermediate Casing Cement -Started @ 5/22/2018 Type Wei@ore Cemented Strlog Cement Evaluation Results Casing MT6-05 I INTERMEDIATE #1, 8,920.8ftKB Did not bump plug, floats held. CIP = 7:21 Hrs Sig If Description Top Depth (ftKB) Bottom Depth (ftKB) D Pump Final... P Pump Final (psi) 1 Intermediate Casing Cement 7,921.0 18,920.8 3 530.0 Fluid I Class A Et (sacks) I Vol Pumped (bbl) Dens gblgal) Yield (Wlsack) Est Top (VIEr Est aM (ftKB) Lead Cement G 104 42.7 12.20 2.31 7,921.0 81421.0 Tail Cement G 241 49.8 15.80 1.16 1 8,421.0 8,920.9 Leak Off and Formation Integrity Tests Leak Dens Fluitl LO Eq Fluid Den off? Last Casing Sting Run I Dep-(ftKB) I ('i Fluid PSud Applied(ps) 1 (I1:19a10 PLeakOelpsi) Yes ISURFACE, 2,014.5ftKB 2,014.01 10.50 1 VVBM b(f.01 16.121 1,655.2 Page 313 ReportPrinted: 9/11/2018 � 7 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: MT6-03 Rig: Doyon 19 Date: 1 3/26/2018 Volume Input Volume/Stroke 0.100018bWstrk ♦ Pump Rate: Drilling Supervisor: K. Harding / D. Wojo Pump used: Mud Pump Strokes ♦ 0.50'SbUm+n Type of Test: Casing Shoe Test LOT/FIT ♦ Pumping down annulus and DP. 'W j Casing Test Shut-in I Pressure Integrity es Pumping Shut-in Hole Size: 12-1/4" IF Casing Shoe Depth _37.0lFt Hole Depth Pumping RKB-CHF: I 207 .0 Ft-M 2052.0 Ft-TVD 2108.0 Ft MD 2080.UF-5- t- D Strks psi 0 20 Min I psi 0 3560 I Strks psi 0 20 Min psi 0.00 360 Casing Size and Description: 13.3/8- eas/Ft L-80 BTC Casing Test Pressure IntegrityTest -2-150 1 3560 1 70 0.25 40 Mud Weight: 9.9 ppg Mud Weight: Mud 10 min Gel: 20.0 Lb/100 Ft2 Mud 10 min Gel: Test Pressure: 3500.0 psi Rotating Weight: Rotating Weight: ###### Lbs Blocks/Top Drive Weight: Blocks/Top Drive Weight 60000.0 Lbs Desired PIT EMW: Estimates for Test: 3.7 bbis Estimates for Test: 1w = eak oif Pressure + u eIq = -" 610 0.052 x TVD0.052 x 2052 + 9'4 EMW at 2078 Ft-MD (2052 Ft-TVD) = 15.1 ppg 1 9.4 ppg 12.0 Lb/100 Ft2 Lbs ##M18.0 60Lbs ppg 918 psi 1 bbis `►' PIT-1 5 -Se-c o n d Shut-in Pressure, psi 4 340 2 3550 2 120 0.50 330 6 520 3 3550 3 21D 1.00 330 8 710 4 3540 4 290 1.50 .0 &v 10 830 5 3540 5 340 12 950 6 3540 6 420 2.50 310 14 1080 7 3540 -7-520 3.00 10 16 1240 8 3540 8 610 3.50 300 18 1320 9 3530 9 450 4.00 30 20-744-0 1075-30 4.50 300 340 22 1580 24 1720 15 3530 20 3520 5.00 290 5.50 290 4000 5 Lost 40 psi during test, a s 26 1880 25 3520 6.00 280 3500 '� a 28 2040 30 2200 30 3520 1 1 6.50 280 7.00 280 a000 32 2360 7.50 280 34 2520 8.00 280 36 2710 1 8.50 280 w 2500 38 2870 9.00 275 40 3020 42 32001 9.50 27F 10.00 y 2000 LU 1 1 44 3360 EL 1500 46 3560 1000 gal Sao AdPIF 0 0 1 2 3 4 Barrels CASING TEST -LEAK-OFF TEST 0 5 10 15 2"25 30 Shut-In time, Minutes 0 PIT PointPum Volume ed Volume Bled Back Volume Pum ed volume Bled Back S s 8 S Comments: Tested casing with 9.9 DrilPlex mud Performed FIT with 9.4 LSND mud VMIIIIIIaly PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: M76-03 I Rig: Doyon 19 Date: 4/2/2018 Volume Input 'W Bbls/Strk Pump Rate: Drilling Supervisor: K. Harding / R. Reinhardt Pump used: Other -See Comments • Barrels Type of Test: ';Annulus leak Off Test for Disposal Adequacy 7 Pumping down annulus. 0.30'',. 9bl/min 4W asmg TestPressure Integrity es Hole Size: 12-1/4" • Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in B-CHF: 37.0 Ft 2078A Ft-MD 2052.0 Ft-TVD 6858.0 Ft-MD 6044,0 Ft-TVD BbIs psi Min psi BbIs psi in psi - --- _ Casing Size and Description: 9.5/8" 40#/Ft L-80 BTC 0 0 0 0.00 382 Changes for Annular Adequacy Test Pressure ntearitVTest 1 0.5 49 0.25 375 nter outer casing shoe test results in comments Mud Weight: 10.1 ppg Casing description references outer casing string. Inner casing OD: 9.6 In. Hole Size is that drilled bel 3500.0 casing. Use estimated TOC for Hole Depth. Enter inner casing 0160000.0 Desired PIT EMW: 15.0 ppg Estimates for Test: 523 psi 0.5 bbls • EMW = ea o ressure + u egg = 465 + 10.1 PIT 15 Second 0.052 x TVD 0.052 x 2052 Shut-in Pressure, psi EMW at 2078 Ft-MD (2052 Ft-ND) = 14.5 375 2 1 4 0.50 50 3 1.5 6 1.00 350 4 2 73 1.50 5 2.5 121 2.00 330 6 3 180 2.50 32 7 3.5 236 3.00 315 8 4 296 3.50 308 9 4.5 356 4.00 302 10 4.75 382 4.50-70 15 5 410 5.00 300 500 Lu U) w 0 0 0 10 20 5.25 440 5.50 300 25 5.5 465 6.00 300 30 5.75 470 6.50 300 6 439 7.00 300 6.25 415 7.50 300 6.5 406 8.00 300 6.75 405 8.50 300 7 403 9.00 300 7.25 399 9.50 na 10.00 7.5 397 7.75 397 15 300 8 396 8.25 396 8.5 396 i Li I I I I L] 8.75 398 9 398 1 oCASING 2 3 TEST d Barrels 8 8 -®--LEAK-OFF 7 B TEST 9 - 0 Shut-In o 5 10 PIT 18 time, Point 20 Minutes 25 30 Volume Pu ed Volume Bled Back Volume Pum,;rd Volu Bled Bae�k s 8 s Comments: Casing shoe LOT 15.1 ppg EMW Used ball mill injection pump #1 MTo 03 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 7 Rig: DOYON 19 Report Date: 3/23/2018 Wellbore Weli Type OFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKS) End Depth (itKH) MT6-03 I Development 2.38 7.0 0.00 2,088.0 2,088.0 Actual Start Date Original Spud Date APE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2018 3/21/2018 57.00 55.16 1.84 5/11/2018 Last Casing String SURFACE, 2,078.2ftKB Ops and Depth @ Morning Report 24hr Forecast @04:00> Displacing cement Circulate, cement casing, ND diverter, NU BOP & test. Last 24hr Summary POOH, hangle BHA, R/U and run 13-3/8" casing, Circ for cement. General Remarks WeaNer Head Count No AIS. Camp on High Line, dg on dg generators. Fog/Mist,•8'F,WC -35', Wind E @ 25 mph, 52.0 Vs=2 mi Suparvrsor TO Ken Harding,Rig Supervisor Rig Supervisor Don Wojciechowski,Rig Supervisor Rig Supervisor Conway Reimer,Rig Engineer Rig Engineer Andy Marushack, Drilling Engineer Drilling Engineer Time Log Start Tme EPWTme Daft) Phase Op coda Ach1t, Cap. T,ma P 4--x Trip] Code Trbl Class Start Depth(aKB) End Dept (WS) DpereGon 00:00 00:15 0.25 SURFAC CASING SRVY P 695.0 695.0 Cont letting gyro fall. Rotate DP 180 deg. 0015 0045 0.50 SURFAC CASING TRIP P 695.0 417.0 POOH f/695'-417 0045 01:00 0.25 SURFAC CASING OWFF P 417.0 417.0 Flow check, slight drop. 01:00 01:45 0.75 SURFAC CASING SHAH P 417.0 125.0 Rack back Hi and jars 01:45 02:15 0.50 SURFAC CASING BHAH P 125.0 125.0 Remove Gyro tool and lay tlown. Rack back flex non -mag DC's 02:15 08:00 5.75 SURFAC CASING SHAH P 125.0 0.0 Handle BHA. Clean large amounts of clay from stabs and tools. Bit Grade: Cones=l-1-W T -A -E -1 -BU -TD PDC=1-1-W T -A -X -1 -BU -TD 0800 0900 1.00 SURFAC CASING SHAH P 0.0 0.0 Clean and clear rig foor 09:00 11:30 2.50 SURFAC CASING RURD P 0.0 0.0 R/U casing tools 11:30 17:00 5.50 SURFAC CASING PUTB P 0.0 1,319.0 PJSM for Tuning casing. M/U shoetrack, Thread lock same, Check floats, run 13-3/8" to 1319' 17:00 18:00 1.00 SURFAC CASING CIRC P 1,319.0 1,319.0 Circulate and condition mud. Stage up to 8 bpm. 18:00 2015 2.25 SURFAC CASING PUTS P 1,319.0 2,038.0 Cont running 13-3/8" casing to 2038' 20:15 21:15 1.00 SURFAC CASING HOSO P 2,038.0 2,078.0 M/U hanger, MN landing joint, torque loose pup to tOK. Run in and land hanger on landing ring. shoe @ 2078'. 21:15 23:15 2.00 SURFAC CEMENT CIRC P 2,078.0 2,078.0 C&C mud. Recip casing 15'. Stage up pumps. Got back a large amount of very thick mud. Max gas = 156 units (mud loggers), (67 units on rig gaswatch). Stage pumps up to 8 bpm, 130 psi. 23:15 23:45 0.50 SURFAC CEMENT RURD P 2,078.0 2,078.0 Blow down TDS. RN cement hose. 1 23:45 00:00 0.25 SURFAC CEMENT CIRC P 2,078.0 2,078.0 Circ through cement hose 8 bpm, 370 psi.. Recip pipe. PU/SO = 1 174/164K. latest BOP Test Data Date Com Page 112 Report Printed: 8/2/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 7 Rig: DOYON 19 Report Date: 3/23/2018 Mud Check Data YP Cak Gal(tos) Gel(10m) Gel(30m) HTHPF,ft to Density Temp Solids, Cm Type Depm(WS) Oms(Wili Vis(skltl PVCek(dF) (181/1000°) (IWICOW) (WTOOR') MV100R?) Willi (nnU30ain) PH (°F) (%) DRILPLEX 2,088.0 10.00 13.0 21.0 12.0 13.0 13.005 14.5 0.0 10.7 68.0 9.5 DRILPLEX 2,088.0 10.00 13.0 38.0 34.0 37.0 36.015 15.0 0.0 10.7 71.0 9.5 DRILPLEX 2,088.0 10.00 14.0 34.0 30.0 35.0 34.014 15.0 0.0 10.7 74.0 9.5 DRILPLEX 2,088.0 10.00 11.0 29.0 32.0 35.0 40.016 16.3 0.0 10.7 76.0 9.3 Injection Fluid Fluid I Source From Lease(hurt Des, Vendor Manifestl4 mber Note Drilling Mud WBM MT6-03 275.0 CDt-01 AES 502652 Mi source well Drill Strings: BHA No.1 - 16" Motor BHA / Bit Run No. 1 - 16m, KM633X, 5279964 Depth In (fti Depth Out (ttKB) TPA (Incl Noz) (W) Nozzles (1172') IIADC Bit Dull String Wt (1000160 115.0 2,088.0 1.22 11/11/11/11/11111/12112112112/12 1 -1 -WT -A -E -O -BU -TD 43 12 Drill String Components its Item Des DD (M) ID (In) Top Conn Se, (in) Top Thread Carta ten (R) Motor with Stabilizer 9 6 518 Reg 31.01 Stabilizer 8 3.00 6 518 Reg 38.23 Drill Collar- Pony 8 3.00 65/8 Reg 47.61 Bottom Slob Sub 81/4 2.88 8 T-2 49.60 Ontrak 81/4 8 T-2 67.99 Modular Stab 81/4 2.88 8 T-2 73.58 BCPM 81/4 2.88 8 T-2 85.23 Modular X.O. 81/4 3.00 8 T-2 88.72 Modular Stab 81/4 2.88 9112 T-2 95.28 APX Sonic Tool 9112 3.00 91/2 T-2 127.76 Top Stop Sub 9 112 3.00 65/8 Reg 131.13 Stabilizer 8 3.00 65/8 Reg 139.39 Filter Sub 8 6 518 Reg 142.42 Drill Collar- Non Mag 8 65/8 Reg 172.71 Drill Collar- Non Mag 8 6 518 Reg 202.67 Drill Collar- Non Mag 8 6518 Reg 231.63 XO Sub 8 3.50 41/2 NC 50 233.62 HWDP 5 3.00 4112 NC 50 325.92 Drilling Jars - Hydraulic 6 114 2.75 4 1/2 NC 50 355.54 HWDP 1 5 3.00 41/2 NC 50 417.30 Wellbores Wellbore Name Wellbore APVUWI MT6-03 501032077000 Section Des Size (in) Ad Top MIKE) Ad Btm (WB) Start Date End Date COND1 42 37.3 115.0 202018 2/3/2018 SURFAC 16 115.0 2,088.0 3/212018 3/22/2018 INTRMI 121/4 2,088.0 8,365.0 3262018 4/32018 INTRM2 83/4 8,387.0 10,224.7 4/9/2018 4/20/2018 PROD2 6 10,224.7 21,764.0 4202018 5/92018 Casing Strings Csp Des I Run Date OD (in) twu en(lPdul Grade I Set Depth (RK8) Com SURFACE 3/23/2018 ij 3181 68.00 1 L-80 1 2,078.2 Page 2/2 Report Printed: 8/2/2018 Security Level: AK Development J� Daily Drilling Report (No Costs) Ankh, MT6-03 Report Number: 8 ft Rig: DOYON 19 Report Date: 312412018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKS) End Depth (ftKB) MT6-03 Development 3.38 8.0 0.00 2,088.0 2,088.0 Actual Start Date Original Spud Date AFE Our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2018 3/21!2018 57.00 55.43 1.57 5/11/2018 Last Casing String SURFACE, 2,078.2ftKB Ops and Depth @ Morning Report 24hr Forecast @04:00> Rill to test BOPE (State and BLM witness) R/U to test, Test BOPE, Test MPD, M/U BHA, RIH, casing test, drill out, FIT, Drill ahead 12-1/4" Last 24hr Summary Circulate, cement casing, ND diverter, NUwellhead. NU BOP General Remarks Weather Heatl Count No AIS. Camp an High Line, rig on rig generators. Fair,-9°F,WC-33°, Wind E @ 18 mph, Vis=10 52.0 mi Supervisor Title Ken Harding,Rig Supervisor Rig Supervisor Don Woiciechowski,Rig Supervisor Rig Supervisor Conway Reimer,Rig Engineer Rig Engineer Andy Marushactc Drilling Engineer Drilling Engineer Time Log Tnep Start Time Entl Tune Dtamn Phase Op Code Activity Co . -T-X Trbl Code Trbl Ch. Start Depth (flim) Entl Dap1h(fixe) Operation 0000 01:00 1.00 SURFAC CEMENT CIRC P 2,078.0 2,078.0 Cont C&C @ 8 bpm, 370 psi. PJSM on cement job. Pump 51 bbl nut plug pill. 01:00 0430 3.50 SURFAC CEMENT CMNT P 2,078.0 2,078.0 SLB flood lines and test to 3500 psi. Pump 101.3 bbl of 10.3 ppg mud push (mixed on the fly). Drop bottom plug. Pump 344.3 bbl of 11.0 ppg lead Cement. Pump 71.8 bbl of 15.8 ppg tail cement Drop top plug. Pump 20 bbl water. Switch to rig pump and displace w/10ppg mud at 8 bpm, 530-800 psi. Slow to 3 bpm, 440-510 psi. Bump plug w/ 2765 strokes. Pressure up to 1010 psi and hold 5 min. Bleed off, floats holding. CIP @ 04:21 hrs. +/-231 bbl cement returned Ito surface. 04:30 05:00 0.50 SURFAC CEMENT WWWH P 2,078.0 2,078.0 Flush riser, function diverter annular and flush again 3x, 05:00 05:30 0.50 SURFAC CEMENT RURD P 2,078.0 0.0 Break out and UD landing joint. 0530 0630 1.00 SURFAC CEMENT RURD P OD 0.0 Clean and clear dg floor. RID Volant tool and casign running tools. UD via beaver slide. 06:30 0830 2.00 SURFAC CEMENT RURD P 0.0 0.0 PJSM. R/D flow lines, bleeder lines. Pull and L/D 90' mousehole . L/D surface riser. 08:30 11:30 3.00 SURFAC CEMENT NUND P 0.0 0.0 N/D diverter annular, knife valve, diverter line. 11:30 14:00 2.50 SURFAC CEMENT NUND P 0.0 0.0 Clean and clear cellar, remove diverter equipment from cellar. 14:00 15:45 1.75 SURFAC WHDBOP NUND P 0.0 0.0 Spot wellhead and adapter in cellar. Install wellhead on surface Casing. 1545 18:45 3.00 SURFAC WHDBOP NUND P 0.0 0.0 Break old adapter from bottom of BOP. Pick up new trip nipple to rig floor. Remove Baker transducer from standpipe. 18:45 21.:00 2.25 SURFAC WHDSOP NUND P 0.0 0.0 N/U BOP, torque bolts to adapter. SIMOPS: Testwellhead seal to 1000 psi / 10 min. Latest BOP Test Data Deb I Com Page 1/2 ReportPrinted: 8/2/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 8 Rig: DOYON 19 Report Date: 312 412 01 8 Time Log Time Stan T,me EIWTane Dur(M) Phase Op Cede Ac"Cade -TX Trbi Cad. Trbl Ctese Start Depth(ii End Deptb(ftKB) Operation 21:00 21:45 0.75 SURFAC WHDBOP MPDA P 0.0 0.0 Install MPD damp and flowline. Test fit long trip nipple. Pull and send to shop for fabrication. 21:45 Oo:oo 2.25 SURFAC WHDBOP NUND P 0.0 0.0 R/U choke hose. Hookup koomey lines. Cleaning pits. Mud Check Data YP oakGet(10.) Get (10.) Get(30m) HTHPFiNdide Density Temp Said., Can. Type Deptn(RKB) pens(11i Vls(s/pO PVCak(di (IbfIt00W) (IM11ooff) (@D10eft� (IEtl1WIN) MT ii (mU30min) pH (49 (%) DRILPLEX 2,088.0 10.00 15.0 21.0 8.0 8.0 9.004 15.0 0.0 10.7 53.0 9.5 DRILPLEX 2,088.0 10.00 18.0. 22.0 7.0 8.0 8.003 15.0 0.0 10.8 52.0 9.5 DRILPLEX 2,088.0 10.00 20.0 18.0 7.0 7.0 8.003 15.0 0.0 10.6 55.0 9.5 DRILPLEX 2,088.0 10.00 13.0 20.0 14.0 15.0 15.006 14.5 0.0 10.6 58.0 9.5 Injection Fluid Fluid Sabi Ram Lease (bbh Dest Vendor Manifest Number Note Cementing Fluids MT6-03 270.0 CDI-01 AES 502653 MT6-03 source well Cementing Fluids MIT -03 270.0 CD1-01 JAES 502654 MT6-03 source well Drilling Mud WBM MT6-03 230.0 CD1-01 JAES 502656 M76-03 source well Drilling Mud WBM MT6-03 250.0 CD1-01 JAES 502655 MT6-03 source well Drilling Mud WBM MT6-03 275.0 CD1-01 JAES 502657 MT6-03 source well Wellbores Wellbore Name Wellbore API/UWI MT6-03 501032077000 Section Des a. (m) Act Top(ftK5) Act Btm(ftK8) Stan Data End Date COND1 42 37.3 115.0 2/3/2018 2/3/2018 SURFAC 16 115.0 2,088.0 3/21/2018 3/22/2018 INTRMI 121/4 2,088.0 8,365.0 3126/2018 4/3/2018 INTRM2 83/4 8,387.0 10,224.7 4/9/2018 4M/2018 PROD2 6 10,224.7 21,764.0 4/20/2018 5/9/2018 Cement Surface Casing Cement - Started @ 3/24/2018 TypeWellbore Cemented String Cement Evaluation Results Casing MT6-03 SURFACE, 2.071 Good CMT returns to surface Stg # IDescription Top Depth (ftKB) Bottom Depth (ftKB) D Pump Final... I P Pump Final (psi) 1 Surface Casing Cement 37.0 2,078.0 8 510.0 Fluid Class Amount (sacks) Vol Pumped (Ebl) Dens(Ib19eQ Yield(ft'/sock) Est top (fiK6) Est start fare) Lead Cement Li[eCRETE 1,007 344.3 11.00 1.92 37.0 1,578.0 Tail Cement G 1 348 71.8 15.80 1.16 1,578.0 1 2,078.0 Page 212 Report Printed: 8/2/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 - Report Number: 14 Report Date: 3/3012018 Rig: DOYON 19 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKB) End Depth (ftKB) MT6-03 Development 1938. 14.0 0.00 8,365.0 8,365.0 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2018 3/21/2018 57.00 56.96 0.04 5/13/2018 Last Casing String SURFACE, 2,078.2ftKB Ops and Depth @ Morning Report 24hr Forecast Running 9-5/8" casing @ 3,900' MD, CBU Continue running 9-518" casing string, C&C for cement. Cement per program Set packoff. Set and test 9-518" storm packer to add 7" spool to wellhead. Last 24hr Summary BRIPOOH, LID BHA 2. Change out and test UPR's. R/U and run 9-5/8" rasing General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on generators. Lt Clouds, 11°F, Wind S 14 mph, WC -5, Ys 56.0 Functioned all rams and annular. Changed UPR's to 9-5.8" and tested. 10 mi Supervisor me Ken Harding,Rig Supervisor Rig Supervisor Rob Reinhardt.Rig Supervisor Rig Supervisor Diana Guzman, Rig Supervisor Rig Supervisor Andy Marushack,Drilling Engineer Drilling Engineer Time Log TmeP Siad Time End Time Dur (Tr) Phase Op Cade Alii" Code -TX TW Code TNI Glass Siad t).W (aKB) ErW Depib (ftKS) Operi 0000 0530 5.50 INTRMI CASING BKRM P 3,411.0 1,995.0 Backream out of hole from 3,411' MD t0 1,995' MD @ 875 gpm, 1890-1740 psi, 4.5-2.5k Tq. Hole unloading large Gay returns from 2,601' MD. P/U=130k, S/0=125k, ROT=120k. 05:30 06:30 1.00 INTRMI CASING CIRC P 1,995.0 1,995.0 Cirmlate and condition @ 900 gpm, 1900 psi, 170 rpm. Pump 3 HV NP sweeps around. Large day chunks returning at shakers. 0630 0800 1.50 INTRMI CASING BKRM P 1,995.0 1,526.0 Continue backream out of casng from 1,995' MD to 1,526' MD @ 875 gpm, 1710 psi, 120-140 rpm w/2k Tq. Pump ll ppg weighted sweep and HV sweeps with NP around, Continuous day returns. 08:00 08:15 0.25 INTRMI CASING OWFF P 1,526.0 1,526.0 OWFF static SIMOPS- C/O Mud pump suction screens. 08:15 09:30 1.25 INTRMI CASING BKRM P 1,526.0 711.0 Continue backreaming out of hole from 1,526' MD to 711 MD @ 875 gpm, 1660 psi, 120-140 rpm, 1k Tq. Power down generator #1 @ 08:30 his, dg on 3 gensets. 09:30 09:45 0.25 INTRMI CASING BOPE P 711.0 680.0 Perform weekly rams function, function annular, UPR's and LPR's (3%" x 6"). Rack back stand to 680' MD. 09:45 10:00 0.25 INTRMI CASING OWFF P 680.0 680.0 OWFF before pulling BHA, static. PJSM on L/D BHA. 10:00 10:30 0.50 INTRMI CASING BKRM P 680.0 401.0 Continue BROOH from 680' MD to 401' MD, racking back HWDP and jars. 850 gpm, 1550 psi. 10:30 11.:15 0.75 INTRMI CASING SHAH P 401.0 159.0 Lay down Baker BHA #2 per DD/MWD reps from 401' MD to 59' MD. 11:15 11:45 0.50 INTRMI CASING SHAH P 159.0 159.0 PJSM, unload and package I I I 1 1 source. 11:45 12:00 0.25 INTRMI CASING BHAH P 159.0 115.0 UD BHA#2 from 159' MD to 115' I I 1 MD. P/U and 510=80k. Latest BOP Test Data Date Com 3/21,/201A ITest BOPE on 5" test it in 9�0/3500 nq for 1n110 min charter! Test annular unn,r and lower IA" x R" VRR'q CV #1-14 4" Demm k Page 113 Report Printed: 8/212018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 14 Rig: DOYON 19 Report Date: 3/30/2018 Time Log StartTme ETens M Dur(hr) Plisse Op Code Ac ty Code TmeP -T-X Trtl Code TMIClass Start Deptli (XKB) End Depth (10<13) Operation 12:00 13:00 1.00 INTRMI CASING BHAH P 115.0 0.0 Continue L/D BHA from 115' MD. Calc Fill=79.37 bbl, Actual fill=244 bbl (GIS). Perform weekly blind ram function test. 13:00 14:15 1.25 INTRMI CASING WWWH P 0.0 0.0 Clean and clear rig floor, M/U stack washer and flush stack @ 650 gpm, 20 rpm. L/D same. 14:15 14:45 0.50 INTRMI CASING BOPE P 0.0 0.0 Drain stack and FMC pulled wear ring. 1445 16:00 1.25 INTRM1 CASING ROPE P 0.0 0.0 Change out Upper Pipe rams from 3W' x 6" VBR's to 9-5/8" casing rams. SIMOPS- R/U Volant tool. 16:00 17:00 1.00 INTRMI CASING BOPE P 0.0 0.0 Set test plug 17:00 17:30 0.50 INTRMI CASING BOPE P 0.0 0.0 R/U to test 9-5/8" rams and annular. 1730 1830 1.00 INTRMI CASING BOPE P 0.0 0.0 Test annular 250/2500 psi and 9- 5/8" UPR's to 250/3500 psi, 10 minutes each charted. 1830 19:00 0.50 INTRMI CASING BOPE P 0.0 0.0 Pull test plug 19:00 1930 0.50 INTRMI CASING BOPE P 0.0 0.0 Set thin wall casing wear bushing 13-3/16" ID 19:30 20:30 1.00 INTRMI CASING RURD P 0.0 0.0 Make up landing joint and hanger, dry run hanger to ensure it will land out. 13-1/16" OD, Mark landing joint and fully landed. Very snug passing through wear bushing. Lay down hanger and landing joint. 20:30 00:00 3.50 INTRMI CASING PUTB P 0.0 765.0 PJSM, PIU and run 9-5/8" 40# 1 I TN80 TXP casing per detail to 765' MD. S/0=95k. Mud Check Data Type Depth(WS) Dens(Iblgap Vis(srat) WCaic(cP) YP Ca1c (11,0Z) GaInos) W1100M Gel(10m) (thuloofm Gel(30m) ppfnapM MET (1b bti HTHPFibrate (m1L30min) pH Density Temp (4) Solids, C. r%) LSND 8,365.0 10.00 39 9.0. 24.0 11.0 14.0 17.007 17.0 0.0 9.6 80.0 11.8 -SND 8,365.0 10.00 42 10.0 26.0 14.0 15.0 18.007 16.0 0.0 9.7 95.0 11.8 LSND 8,365.0 10.05 41 9.0 28.0 14.0 15.0 17.007 17.0 0.0 9.5 96.0 11.5 LSND 8,365.0 10.10 41 9.0 29.0 13.0 15.0 19.008 18.0 9.4 94.0 12.0 Injection Fluid Fiuk 5aurce I From Lease(bbp I Dent I Vendor Manifest Number I Note Drilling Mud WBM MT6-03 40.0 CD1-U1 IAFb29486 MT6-03 source well Drilling Mud WBM MT6-03 235.0 CD1-01 AES 529485 MT6-03 Source well Dulling Mud WBM MT6-03 275.0 CD1-01 JAES 529484 MT6-03 source well Drill Strings: BHA No. 2 - 12.1/4" AutoTrack BHA / Bit Run No. 2 - 121/4in, DD605SX, 5281206 Depth in (ftKB) Depth Out (nKB) TFA (Inc[ Noz) (W) Nozzles (1132' IADC Bit Dull String M (10001bf) 2,088.0 8,365.0 1.02 12/12/12!15/15/15/15 1-1-BT-G-X-1-WT-TD 202 Drill String Components Jra Item Des DO (in) 10(m) Tap Conn Sz(in) Top Thread Cum Len (ft) AutoTrak Steering head 11.86 2.48 9 12 T2 11.87 Flex sub w/Stab 121/8 3.12 91/2 T2 20.95 NM X/O sub 9112 3.50 81/4 T2 23.99 OnTrak -MWD 81/4 2.75 81/4 T2 42.69 Mod stab 121/8 2.88 81/4 T2 48.54 BCPM 81/4 2.88 81/4 T2 59.88 Page 2/3 ReportPrinted: 8/212018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 14 Rig: DOYON 19 Report Date: 3/30/2018 Drill String Components Jta Item Dee OD(im !D (n) Top Conn Sz(in) Top Thread Co. Led (ft) ORD 81/4 2.64 81/4 T2 68.44 CCN 81/4 2.81 81/4 T2 76.93 Mod stab 121/8 3.00 8114 T2 82.78 SoundTmk 81/4 3.20 81/4 T2 115.11 Mod stab 121/8 3.00 81/4 T2 118.97 Stop sub 81/4 3.13 6 516 Reg 120.83 Filter 81/4 2.75 6 518 Reg 123.86 Float 8 2.75 65/8 Reg 125.77 Float 715/16 2.75 65/8 Reg 128.88 3 NMDC 8 2.75 6 518 Reg 218.09 X/O sub 8 2.75 4 112 IF 220.08 12 HWDP 5 3.00 41/2 IF 588.66 Jars 6.258 2.75 41/2 IF 618.28 2 HWDP 5 3.00 4112 IF 680.04 244 Drill Pipe 1 5 4.28 4 112 IF 8,365.00 Drilling Parameters Flow Rate Sian Oeptb (me) End Dagh (Wm Cum Dean( Cum DNI Ame(hr) Slitling Time (hr) (9pm) Wpm) WOB it00-. RPM (rpm) sPP(pv) PD Str W1 (10001bt) DrIIIStr" (10=b9 SOStrm (10004bf) OA Ban Tq Ddl To 8,365.01 8,365.0 6,277.00 43.70 1 8701 20 1 160 1 2,900.0 1 2421 2031 172 7.5 1 18.0 Wellbores Wellbore Name Wellbore APIIU WI MT6-03 501032077000 Section Das Size on) Act Top m!<B) An End (WS) Stan Data End Date CONDI 42 37.3 115.0 2!3/2018 2/3/2018 SURFAC 16 115.0 2,088.0 3/21/2018 3/22/2018 INTRMI 12114 2,088.0 8,365.0 3/26/2018 4/3/2018 INTRM2 83/4 8,3820 10,224.7 4/92018 4/20/2018 PROD2 6 10,224.7 21,764.0 4/202018 5/912018 Page 3/3 Report Printed: 8/212018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 15 =�'Rig: DOYON 19 Report Date: 3/31/2018 Wellbore Well I Type DFS (days) DOL (days) Depth Progress (rt) Stan Depth (ftKS) End Depth (ftKB) MT6-03 Development 10.38 15.0 0.00 8,365.0 8,365.0 Actual Start Date 1 Original Spud Date AFE our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/17/2018 3/21/2018 57.0(1 57.34 -0.34 5/13/2018 Last Casing String INTERMEDIATE 1, 8,354.2ftKB Ops and Depth @ Morning Report 24hr Forecast N/ D BOPE, casing/packoff tested, storm packer set/ tested. Setftest packoff. Set and test 9-5/8" storm packer to add 7" spool to wellhead. C/0 UPR's, test rams and breaks. Flush and FP annulus. Pull storm packer, MN PH BHA 43. Last 24hr Summary Continue running 9-5/8" casing stung, C&C for cement. Cement per program. Bump plug and test floats good. L/D landing it, pull wear ring. General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on generators. Lt snow, 11°F, Wind W 22 mph, WC-8, vs 57.0 Daily cost reflects Intermediate 1 rasing and cement. 1.75 m Supervisor litla Ken ftarchng,Rrg Supervisor Rig Supervisor Rob Reinhardt.Rig Supervisor Rig Supervisor Diana Guzman,Rig Supervisor Rig Supervisor Andy Marushack,Drilling Engineer Drilling Engineer Time Log Thep Stan Tme End Tree Dur(hr) Phase Op code Activity Code -T-X Tdd Cade Trhl Cie. Start Depth(IKa) End Depth (WS) Operation 00:00 05:30 5.50 INTRM7 CASING PUTS P 765.0 3,949.0 P/U and RIH with 9-5/8" casing from 765' MD to 3,949' MD. 05:30 06:30 1.00 INTRMI CASING CIRC P 3,949.0 3,949.0 Circulate and condition hole, stage up from 2 bpm to 7.5 bpm, 170 psi. P/U=180k, S/0=165k. 0630 1200 5.50 INTRMI CASING PUTS P 3,949.0 7,524.0 Continue P/U and RIH with 9-5/8" casing per detail from 3,949' MD to 7,524' MD. 190 its in hole, SOW=225k 1200 14:00 2.00 INTRMI CASING PUTS P 7,524.0 8,316.0 Continue P/U and RIH with 9-5/8" casing per detail from 7524' MD to 8,316' MD. 209 its in hole, SOW=220k 14:00 14:15 0.25 INTRM7 CASING HOSO P 8,316.0 8,316.0 Make up hanger and landing joint. 14:15 14:30 0.25 INTRMI CEMENT WASH P 8,316.0 8,354.0 Break circulation @ 1 bpm, wash down and land casing on hanger, 8,354' MD shoe depth. 14:30 17:45 3.25 INTRMI CEMENT CIRC P 8,354.0 8,354.0 Circulate and condition mud for cementing, stage up to 8 bpm, 350 psi FCP. Reciprocate 10' only due to hanger catching on lower ram Cavity. Pumped full surface to surface to condition mud. 17:45 18:15 0.50 INTRMI CEMENT RURD P 8,354.0 8,354.0 Blow down top drive, R/U cementing equipment. 18:15 20:00 1.75 INTRMI CEMENT CMNT P 8,354.0 8,354.0 PJSM, Pump cement job per program. Flood lines with water and PT to 4000 psi-good. Blend and pump 60 bbl 12.0 ppg MudPush @ 3.5 bpm, 500 psi. Drop bottom plug, blend and pump 41.2 bbl 12.2 ppg Lead cement @ 5 bpm, 865 psi followed by 48.6 bbl 15.8 ppg Tail cement @ 4.8 bpm, 925 psi. Drop top plug, kick out with 20 bbl fresh water from SLB, 5.5 bpm 600 psi. Latest BOP Test Data Data Cam it 3/9.�onip Ted RnPr rn W test it to 9qn/3.�On os far 10/10 min chni-ted Test nnnulAr un�r and lower 31/" x A" VRR'q CV #1-14 X' nern,on k Page 1/3 Report Printed: 8/2/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 15 ft -Rig: DOYON 19 Report Date: 3/31/2018 Time Log T. P Start Time End Tme Durthn Prase op Code Actvlty Code -T-x TrWCode Trbl Class Start Deplh(ftKl End Deptlitti Cpereflon 20:00 21:30 1.50 INTRMI CEMENT CMNT P 8,354.0 8,354.0 Displace cement with rig pumps, 10 ppg LSND @ 8 bpm, 900 psi FCP, reduce to 3 bpm 600 psi to bump plug. Bumped plug @ 6040 silks, pressured up to 11 psi and hold for 5 min, increase pressure to 1500 psi for 10 minutes charted testing casing. Bleed off pressure and check floats, holding. CIP @ 21:19 hrs. 21:30 22:00 0.50 INTRMI CEMENT RURD P 8,354.0 8,354.0 Blow down, rig down Volant CRT and casing / Cementing equipment. 22:00 22:30 0.50 INTRMI CEMENT RURD P 8,354.0 0.0 Lay down landing joint. 22:30 00:00 1.50 INTRMI CEMENT WWSP T Wellhead/ Other 0.0 0.0 MN wear bushing puller tool, Tree attempt to pull bushing. Could not get running tools through stack to J into wear ring due to tight tolerance between running tool and ID of ROPE. Unable to get past blind rams lower ID. Mud Check Data YP Calc Gel(10s1 Gel(10m) Gel (30m) HTHPFii Density Temp Solids, Corr. Type Depth(ftl(B) Dens ati Vts(si PVCalct,P) (1b11100W) (ItA1100th Pbt/IDOft') (MfIt00tP) MBT(RcUt, (rnISomin) pH (°F) (%) LSND 8,365.0 10.00 44 9.0 25.0 11.0 13.0 15.006 18.0 0.0 9.2 79.0 11.0 LSND 8,365.0 10.00 44 9.0 25.0 13.0 14.0 16.007 18.0 0.0 9.5 70.0 11.0 LSND 8,365.0 10.00 45 9.0 26.0 13.0 15.0 17.007 18.5 0.0 9.5 70.0 11.5 LSND 8,365.0 10.00 41 9.0 28.0 14.0 15.0 18.007 18.8 9.4 90.0 11.8 Injection Fluid Fluid Source From Lease(but pest Vendor Manifest Number Note Drilling Mud WBM MT6-03 45.0 CDI-01 AES 529487 MT6-03 source well Drilling Mud WBM MT6-03 45.0 CDI-01 AES 529489 MT6-03 source well Drilling Mud WBM MT6-03 205.0 CDI-01 AES 529488 MT6-03 source well Oniling Mud WBM MT6-03 230.0 CD1-01 AES 529490 MT6-03 source well Interval Problems Start Date Start Depth (Ii I End Depth(ftKS) Trouble Code Trouble Class wellbore 3/31/2018 1 0.01 0.0 1 Non -rig Surface Eqp Other Auxilliary Eq. IMT&03 Welibores Wellbore Name Wellbore APIIUWI MT6-03 501032077000 Sail Des Size (Ii An Top (ftKB) Act Ben (ftKB) Start Date End Dale COND1 42 37.3 115.0 2/3/2018 2/312018 SURFAC 16 115.0 2,088.0 3/212018 3/22/2018 INTRMI 121/4 2,088.0 8,365.0 3262018 4/3/2018 INTRM2 8314 8,387.0 10,224.7 4192018 4202018 PROD2 6 10,224.7 21,764.0 420/2018 5/9/2018 Casing Strings Csg Des Run Date OD (m) lvad-en(wel Grade 1 Set Depth dtKB) Com INTERMEDIATE 1 3/31/2018 1 95161 40.00 1 L-80 1 8,354.2 Cement Intermediate Casing Cement -Started@ 3/31/2018 Type allbore Cemented String Cement Evaluation Results Casing MT6-03 INTERMEDIATE 1, 8,354.2RKB Stg # Description Top Depth (ftKB)Bottom Depth (ftKB) D Pump Final... P Pump Final (psi) 1 Intermediate Casing Cement 7,354.0 8,365.0 3 610.0 Fluitl Class Amount (sacks) I Vol Pumped (bbl) I Dens (Iblgal) I Yield (IP/sack) I Est Top (ftKB) I Est Btm (ftKB) Lead Cement 1 1001 41.21 12.201 2.301 7,354.01 7,854.0 Page 2/3 Report Printed: 82/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-03 Report Number: 15 Report Date: 3/31/2018 Rig: DOYON 19 Fluid Class Amount (sacks? Vol Pumpetl (bbl) D,n (Ib/gap Y.Id (M/sack) Est Top(ftKB) Est at.(N(B) Tail Cement G 234 48.6 15.80 1.16 7,854.0 8,365.0 Page 313 ReportPrinted: 812/2018 Cement Detail Report MT6-03 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3117/2018 12:00 Cement Details Description Surface Casing Cement Cementing Staff Date 3/24/2018 01:00 Cementing Entl Date 3/242018 04:30 WellboreName MT6-03 Comment Cement Stages Stage # Description Surface Casing Cement Object Top Depth (ttKB) 37.0 Bottom Depth (ftKB) 2,078.0 Full Return? Yes Vol Cement... 231.0 Top Plug? Yes letmYes Plug? Yes O Pump Init (bbllm... 5 IQ Pump Final (bbi/... 18 IQ Pump Avg (bbll... 6 P Pump 5%0 Final (psi) P Plug Bump (psi) Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Grill Bit Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment Cement Fluids 8 Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 37.0 Est Earn(hKB) 1,578.0 Amount (sacks) 1,007 Class Volume LiteCRETE 344.3 Pumped (bbl) Yield (fPlsack) 1.92 Mix H2O Ratio (gallsa... 6.8 Free Water (%) 1 Density (Iblgal) 1 11.00 Plastic viscosity (cP) 258,000.0 Thickening Time (hr) CmprStr 4.00 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimatetl Top (ftKB) 1,578.0 Est Btm (ftKB) 2,078.0 Amoum (sacks) 348 Class Volume G Pumped (bbl) 71.8 Yield (ft-Isack) 1.16 Mix H2O Ratio (gallsa... 5. Free Water [%) 1 Density (lblgal) 15.80 Plastic Viscosity (CP) 145,000.0 Thickening Time (hr) 4.40 CmprStr i (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 8/1/2018 Cement Detail Report MT6-03 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3117/2018 12:00 Cement Details DescriptionCementing Intermediate Casing Cement Start Date 3131!2018 18:45 Cementing End Date 3/31/2018 21:15 Wellbore Name MT6-03 Comment Cement Stages Stage lf 1 DescriptionObjective Intermediate Casing Cement Achieve 1000' cement from shoe up Top Depth (ftKB) 7,354.0 Bottom Depth (ftKB) 8,365.0 Full Return? Yes Vol Cement... Top Plug? Yes Btm Plug? Yes Q Pump Mit (bbllm... 8 Q Pump Final (bbif... 3 Q Pump Avg (bbll... 8 P Pump 610.0 Final (psi) P Plug Bump (psi) 1,200.0 Recip7 Yes Stroke (ft) 10.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid DescriptionEstimated Top (ftKB) 7,354.0 Est Btm (ftKB) 7,854.0 Amount (sacks) 100 Class Volume G 41.2 Pumped (bbl) Yield (ft-/sack) 2.30 Mix H2O Ratio (gailsa... 13.53 Free Water rQ Denstty abigal) 12.20 Plastic Viscosity (CP) 17,000.0 Thickening Time (hr) CmprStr 5.50 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description 1 Estimated Top (ftKB) 7,654.0 Est Btm (ftKe) 8,365.0 Amount (sacks) 234 Class Volume G 48.6 Pumped (bbl) Yield (ft'/sack) 1.16 Mlx H2O Ratio (gal/sa... 5. Free Water (Y) 1 Density (Ibigap 15.80 Plastic Viscosity (CP) 131,000.0 Thickening Time (hr) CmprStr 4.00 i (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 8/1/2018 MT6=08 d m M 16 c L ou> 0 0 0 0 0 0 0 o.Ev� - 'moi ' u� o u> o 'd o, C o aivv vi ui� r,: roao pi m E m w 7 a M C O O omf (00 VN (OpN tO°O6> w O G �N N C Vl 47 t0 I+ i� W O 1 N E to a 0 E p aY a' m Y O � 00 O 000 00 � W m O Yw to y N M N N N N N N p E N E 0 p.........._...... > > m O 00 a+ L O M 7 O O �O N �10 O i O C m O � �+ C 0000 00 O O O tp O O O o 00 in w R N Ci' C7 O 7 V N t O O N N MOI C N NDN d a £ E E y O V CO N 7 (O GO N V'CDcoON V cpNON V O E 3 N NN Mn =Lq Y a o j o N .r w Y O O. O r n a o.vwo I�°o m oc N a « a a a m a'a ivi aU) IL a` i E deo 00 E W U) d a c o' o CL e ._... x y Z ,J o c.. �,,_ .c o o a W a a w o a LL111111111 N ° Hill I I L rn° erm crH O DO U O. O. NL Ul ON w L i o ui E E w > E�m� p U) Z rn a a 5o mea w } W O Cl c p j o N N Omm a o R ��„�E °'� m p S',, OW 1 � 7 L 0' ® o K CL UI Vm m co N LL O QM O O Q L LL a w r LL 1 c ,Im v T E E m c LL o n tr o w p a y - d' c 0�0 0 am LL rm ai L V N O LL w N + N z c A n O C N L Ow OI c) 0 l0 ¢ w N y m E a m w `� aW ayi d yc`� E m T ti m U Y W M MnSSMd E d Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 3 Rig: DOYON 19 Report Date: 7/16/2018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKB) End Depth (ftK6) MT6-08 Development 0.93 3.0 1,505.00 1 115.0 1,620.0 Actual Start Date Original Spud Date JAFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/14/2018 7/16/2018 151.65 52.42 -0.77 9/4/2018 Last Casing String 20" conductor, 11&0ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating @ TD of 2,021' Drill to TD of 2,021'. Circ hole clean & wt up to 10.0 ppg. POOH & LID BHA.RAJ &run 13-3/8" casing & cement Last 24hr Summary Fix leaking riser. Fill hale & check leaks (goad). Drill 16" Surface to 1,620' (Had issues with clay attacks and packing off flow line) General RemarksWeather Head Count No AIS. Camp on High Line @ CD5. Rig on generators as 05:30 7/9/18Hrs. Overcast, 43`F, Wind NW 6 mph, Vis 10 m 53.0 Supervisor Tde Ken Harding,Rig Supervisor Rig Supervisor Adam Dorr,R!g Supervisor Rig Supervisor Nina Woods Anderson ig Engineer Rig Engineer Tan Polassk, Drilling Engineer Drilling Engineer Adam Klem,Completions Engineer Completions Engineer Time Log ime P Stan Time EnA T1me Dur (hr) Phase Cp Code ACovity Code -T-X Trbl Code Tile! Cless Start Dash (id(1h End Dept (02) Operalbn 00:00 01:15 1.25 MIRU MOVE RURD T Rig Riser DO 0.0 Lift riser& replace gasket& Silicone. Fill conductor & check for leaks. (good) 01:15 01:45 0.50 MIRU MOVE REAM P 0.0 115.0 P/U stand of HWDP & RIH w/BHA to 93'. Break circ w/450 gpm, 500 psi, 40 rpm, 4 k trq & clean out to bottom of conductor @ 115- 01:45 0215 0.50 SURFAC DRILL DDRL P 115.0 132.0 Drillahead f/115'to 132' 02:15 02:30 0.25 SURFAC DRILL RGRP T Rig Ball 132.0 132.0 Replace belts on ball mill drag Mill /Cuttin chain. gs. 02:30 03:15 0.75 SURFAC DRILL DDRL P 132.0 185.0 Drill ahead f/132'to 185' 03:15 04:00 0.75 SURFAC DRILL BHAH P 185.0 185.0 POOH 1/132'to 185'. LID HWDP & P/U NMFC's. RIH to 185' 04:00 1030 6.50 SURFAC DRILL DDRL P 185.0 785.0 Drill ahead f/185'to 785' 10:30 11:30 1.00 SURFAC DRILL CLEN T Hole Other 785.0 785.0 Clay Attack!!! Flow line & polution Conditions pan packed offwith clay. Stop drilling & clean out packed off clay. 11:30 12:00 0.50 SURFAC DRILL DDRL P 785.0 836.0 Drill ahead 1/785' to 836' MD / 836' TVD, ADT 5.7 Hrs, 650 gpm, 1300 psi, PU wt 92 k, SO wt 92 k, ROT wt 92 k, 60 rpm, 4 11.5 k ft/Ibs trq. 12:00 12:45 0.75 SURFAC DRILL DDRL P 836.0 920.0 Drill ahead 1/836' to 920' 12:45 14:00 1.25 SURFAC DRILL CLEN T Hole Other 920.0 920.0 Clay Attack!!! Flow line & polution Conditions pan packed off with day. Stop drilling & dean out packed off clay. Re -shoot survey 14:00 14:30 0.50 SURFAC DRILL SRW P 920.0 920.0 Shoot MWD survey 14:30 14:45 0.25 SURFAC DRILL DDRL PI 920.0 932.0 Drill ahead f/920' to 932' 14:45 16:00 11.25 SURFAC JURILL SRW IFI 1 1932.0 932.0 R/U Gyro & shoot survey., Latest BOP Test Data Date it Com Page 113 ReportPrinted: 9111/2018 Security Level: AK Development AL Daily Drilling Report (No Costs) MT6-08 Report Number: 3 Rig: DOYON 19 Report Date: 7/1612018 Time Log Time P Start T,me End Time Dur(hr) Phase Op Code AcWty Code -T-X TAI Code TrdI Class Sw Depth(XI®) End Depth(WB) Operation 16:00 00:00 8.00 SURFAC DRILL DDRL P 932.0 1,620.0 Drill ahead f/932'to 1,620' MD I 1,612' TVD, ADT 5.2 His (3.1 Rotate 12.1 Slide), 850 gpm, 2350 psi, PU wt 105 k, SO wt 105 it, ROT wt 105 k, 70 rpm, 512 k ft/lbs trq. (Slight How line pack off Q 1,412') Pumping nut plug sweeps to aid in Gay attacks 8 bit balling. Mud Check Data YPCek Gal (10s) Gal(10.) Get(30m) HTHPritrate DensityTemp Solds, Car. Type Depth (QKB) Dan.(BVgeQ Vis(s19t) PVCak(cP) (IMM00111 QNllapft7 (W/100e1 (11,9100ftq MST QPNpO dant J min) PH ff) I%) DRILPLEX 1,335.0 9.70 8.0 45.0 45.0 46.0 49.000 14.0 10.8 65.0 7.5 DRILPLEX 930.0 9.65 7.0 55.0 49.0 57.0 60.000 15.0 10.6 66.0 7.0 DRILPLEX 463.0 9.65 8.0 41.0 42.0 50.0 53.000 12.0 10.8 65.0 6.0 DRILPLEX 165.0 9.50 6.0 50.0 46.0 52.0 54.000 8.3 11.2 63.0 6.0 injection Fluid Flied Source From Lease best Vendor Manifest Number Note Drilling Mud WBM MT6-08 250.0 CDt-01 AES 529654 MT6-08 Source Well Drilling Mud WBM MT6-08 250.0 0131-01 AES 529655 MT6-08 Source Well Drilling Mud WBM MT6-08 275.0 CDt-01 AES 529658 MT6-08 Source Well Drilling Mud WBM MT6.08 275.0 CDI.01 AES 529659 MT6-08 Source Well Drilling Mud WBM MT6-08 275.0 CD1-01 AES 529656 MT6-08 Source Well Drilling Mud WBM MT6-08 275.0 CD1-01 AES 529657 MT6-08 Source Well Drill Strings: BHA No. 1 - 16" Surface Motor BHA 1 Bit Run No. 1 RR - 16in, KM633X, 5279964 Depth In (ftKB) Depth Out(ftKB) TPA (Incl Noz) (n') Nozzles (1132") 1 IADC Bit Dull SMng Wt (10001b0 115.0 2,021.0 1.22 11!11/11!11111/11112/12112112/12 1 -1 -WT -A -E -0 -BU -TD 66 12 Drill String Components its Item Des OD 0n) ID (in) Top Cann S (in) Top Thread Cum Len (m Motor with Stabilizer 9 3.00 6 518 Reg 31.47 Stabilizer 15 3.00 65/8 Reg 38.72 Drill Collar - Pony 8 3.00 6518 Reg 48.10 Bottom Stop Sub 8114 2.88 8 T-2 50.77 Ontrak 81/4 8 T-2 69.44 Modular Stab 12114 2.88 8 T-2 75.22 BCPM 81/4 2.88 8 T-2 86.53 Top Stop Sub 91/2 3.00 65/8 Reg 87.98 Filter Sub 8 65/8 Reg 91.01 Orienting Sub 8 3.00 6 518 Reg 93.10 Drill Collar - Non Mag 8 65/8 Reg 123.04 Drill Collar- Non Mag 8 65/8 Reg 152.01 Drill Collar- Non Mag 8 65/8 Reg 182.32 XO Sub 8 3.50 41/2 NC 50 185.72 3 HWDP 5 3.00 41/2 NC 50 277.78 Drilling Jars - Hydraulic 6 114 2.75 41/2 NC 50 307.32 2 HWDP 5 3.00 41/2 NC 50 369.04 52 Drill Pipe 5 4.28 4 112 NC 50 2,021.00 Drilling Parameters Flow Ra e Star) Depth End Depth %ding (Qpm) WOB RPM I PU Str m OdQStrm SQ So- m I (ftKe) (MR) Cum Depth (a) Cum Dmi Tfine(hrl Time inn (gPm) 000ebH (rpm) SPP (psp (tOW@f) (1000Wp (10001b0 ORBMTG Dre To 115.0 836.0 721.00 5.70 650 12 60 1,300.0 92 92 92 1.5 4.0 836.0 1,620.0 1,505.00 10.90 2.10 850 1 17 70 2,350.0 105 105 105 2.0 5.0 Page 213 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) =6R-ig:9 MT6-08 Report Number: 3 Report Date: 711612018 Interval Problems Stan Date Start Depth (N<B) End Dep111 KKB) Trouble Code Trouble Claes Wellbare 7/16/2018 132.0 132.0 Rig Ball Mill /Cuttings. MT6-08 7/16/2018 785.0 1,412.0 Hole Conditions Other MT6-08 Wellbores Wellbore Name Wellbore APIIUWI MT6-08 501032077200 Section Dee Slee (in) Act Tap (ftKB) Act S. (NCB) Stan De[e End Date CONDI 42 36.6 115.0 2/612018 2/6/2018 SURFAC 16 115.0 2,021.0 7/16/2018 7/19/2018 INTRMI 121/4 2,021.0 10,330.0 7/19/2018 7/28/2018 83/4 10,328.0 12469.5 8/9/2018 8119/2018 INTRM2 12,469.5 21,102.0 8M9/2018 9/5/2018 PRODt 6 Survey Data MD (NCB) Azm (°) NO (fiKB) VS (h) NS (ft) Ew(rc) Des(°no0tp 115.00 0.00 72.88 115.00 -0.07 0.11 0.36 1.00 115.00 0.61 68.68 115.00 -0.07 0.11 0.36 1.00 210.38 0.78 87.34 210.37 -0.41 0.33 1.48 0.29 301.40 0.79 84.73 301.38 -0.92 0.41 2.73 0.04 393.91 0.42 82.05 393.89 -1.28 0.52 3.70 0.40 489.21 0.37 282.55 489.19 -1.20 0.63 3.74 0.82 583.84 0.51 272.65 583.81 -0.79 0.72 3.02 0.17 677.91 1.34 323.48 677.87 0.51 1.62 1.95 1.16 771.90 1.35 323.29 771.84 2.69 3.39 0.63 0.01 831.00 1.97 322.36 830.91 438 4.76 -0,40 1.05 924.00 2.75 329.74 923.83 8.19 7.95 -2.50 0.90 960.17 3.29 328.86 959.95 10.09 9.59 -3.48 1.50 1.055.06 4.75 333.42 1,054.61 16.74 15.43 -6.64 1.57 1,149.35 6.33 335.43 1,148.45 25.83 23.65 -10.55 1.69 1,243.45 7.86 337.92 1,241.83 37.41 34.33 -15.13 1.66 1,336.749.05 330.92 1,334.11 51.09 46.65 -21.09 1.68 1,431.33 10.59 328.44 1,427.31 67.20 60.56 -29.26 1.69 1,525.76 12.70 330.41 1,519.79 86.24 76.98 -38.93 2.27 1.619.64 14.31 331.05 1,fi11.07 108.16 96.11 -49.64 1.72 Page 313 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 4 Rig: DOYON 19 Report Date: 7/17/2018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKI3) End Depth (ftKB) MT6-08 Development 1.93 4.0 401.00 1,620.0 2,021.0 Actual Start Date Original Spud Date 1AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7114!2018 7/16/2018 151.65 52.22 4,57 9/4/2018 Last Casing String 20" conductor, 115.OftKB Ops and Depth @ Morning Report 24hr Forecast Circulating for Cement Job Cont. to run casing & land on hanger @ 2,010'. Circ & wind for cement job. Cement casing as per SLB. N/D riser & annular. NIU BOPE & MPD. Last 24hr Summary Drill to TD of 2,021'. Circ hole clean & wt up to 9.9 ppg. POOH & L/D BHA RID to run Casing. RIH 13-3/8" rasing to 1,425' General Remarks Weather Head Count Incident - First Aid. Camp on High Line @ CD5. Rig on generators as 05.30 7/9/18HM. Overcast, 537, Wind S 8 mph, Us 10 m 52.0 Supervisor Title einhardt,Rig Supervisor Rig Supervisor Adam DorCRig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Tom Polasek,Drilling Engineer Drilling Engineer Adam Klem,Compietions Engineer Completions Engineer Time Log TimeP Stan Time End Tme Dur(hr) Phase Op Code Acvvity Code 4-X TNI Code Trbl Cuss SWMDeplh(ftKa) End DepN(aKS) Operation 00:00 0400 4.00 SURFAC DRILL DDRL P 1,620.0 2,021.0 Drill ahead f/1,620" to TD of 2,021' MD 11,993' TVD, ADT 3.0 firs (1.6 Rotate 11.4 Slide), 850 gpm, 2450 psi, PU wt 122 k, SO wt 120 k, ROT wt 121 k, 70 rpm, 5.5 / 2.5 k fUlbs trq. Pumping nut plug sweeps to aid in clay attacks & bit balling. 04:00 06:00 2.00 SURFAC CASING CIRC P 2,021.0 1,872.0 Pump nut plug sweeps & circ hole clean w/900 gpm, 2400 psi, 80 rpm, 2.5 k trq. Increase mud wt to 9.9 ppg. Racked back 2 stands (/2,021' to 1,872' 06.00 06:15 0.25 SURFAC CASING OWFF P 1,872.0 1,872.0 FIG (static) 06.15 08:00 1.75 SURFAC CASING TRIP P 1,872.0 369.0 POOH f/1,872'to 369' 0800 08:15 0.25 SURFAC CASING OWFF P 369.0 369.0 F/C(static) 08:15 09:00 0.75 SURFAC CASING TRIP P 369.0 93.0 Rack back HWDP, Jars, & NMFC 09:00 09:15 0.25 SURFAC CASING CIRC P 93.0 93.0 Pump nut plug sweep & circ BHA clean w/875 gpm, 1540 psi, 50 rpm, 1 k trq. 09.15 11:00 1.75 SURFAC CASING BHAH P 93.0 0.0 L/D BHA as per Baker reps 11:00 1145 0.75 SURFAC CASING BHAH P 0.0 0.0 Clean& clear floor of BHA tools& equipment. SIMOPS - Clean suction & discharge on both mud pumps. 11:45 13:00 1.25 SURFAC CASING RURD P 0.0 0.0 R/U to run Casing. MAJ Volant. R/U bale extensions & spiders. Bring up power tongs via beaver slide & floor hand had incident with tugger line. 13:00 13:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Safety shut down & re -focus from tugger incident 13:15 15:00 1.75 SURFAC CASING RURD P 0.0 0.0 R/U power tongs, strap tongs, & safety valves. 15:00 15:15 1 25 SURFAC ICASING SFTY P 0.01 0.0 PJSM on running casing 15:15 22:15 7.00 SURFAC CASING PUTB P 0.0 1,301.0 MID shoe track & check floats I I (good). RIH w/13-3/8" 68# L-80 1 TXP casing to 1,301' Latest BOP Test Data Date Gam it Page 113 ReportPrinted: 9/11/2016 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 e Report Number: 4 Report Date: 7/17/2018 Rig: DOYON 19 Time Log TmeP startTnme EM Time Dorm Phase Op Code Activity Cade -LX Trbl Code Th] Clare Start Depth (N(B) End Depth (ftKB) Operation 22:15 23:15 1.00 SURFAC CASING CIRC P 1,301.0 1,301.0 Break circ & stage pumps to 8 bpm / 150 psi. Circ surface to surface. PU wt 135 k 1 SO wt 125 k 23:15 00:00 0.75 SURFAC CASING PUTB P 1,301.0 1,425.0 Cont to RIH w/13-3/8" 68# L-80 TXP casing f/1,301'to 1,425'. PU wt 160 k/SO wt 100k 'Mud Check Data YP Calc GO (10.) GO (10.) CN M.) HTHP Rrate DeONtylamp Solids, Cort. Type DepN (dxa) Dan. (Ib/gat) Ms (srgt) PV Cak (cP) (Ibfilm P) (Ibuloof19 (Ib( IOW) (11,0100" MET (IbZb0 (mL630mT) pH P77 (%) DRILPLEX 2,021.0 9.90 17.0 38.0 31.0 48.0 54.000 19.8 10.7 75.0 10.0 DRILPLEX 2,021.0 9.90 13.0 36.0 35.0 52.0 60.000 18.8 10.6 93.0 9.5 DRILPLEX 2,021.0 9.90 14.0 38.0 36.0 54.0 62.000 18.8 10.6 98.0 9.5 DRILPLEX 1,909.0 9.80 11.0 38.0 37.0 52.0 56.000 20.0 10.7 81.0 9.0 Injection Fluid Fluid Source From Lease (bbl) I Net I Vendor I Menest Number Note Drilling Mud WBM MT6-08 275.0 CD1-01 AES 529660 MT6-08 Source Well Drilling Mud WBM MT6-D8 275.0 1 CD1-01 AES 529661 MT6-08 Source Well Drill Strings: BHA No. 1 - 16" Surface Motor BHA I Bit Run No. 1 RR - 16in, KM633X, 5279964 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (In-) Nozzles (1/32") IADC Bit Dull String Wt (10001bq 115.0 2,021.0 1.22 11/11/11/11/11/11/12/12/12/12112 1 -1 -WT -A -E -0 -BU -TD I 66 112 Drill String Components its Item Des Do (in) ID (,n) Top Conn So(in) Top Thread Cu. en (A) Motor with Stabilizer 9 3.00 65/8 Reg 31.47 Stabilizer 15 3.00 65/8 Reg 38.72 Drill Collar- Pony 8 3.00 6 518 Reg 48.10 Bottom Stop Sub 81/4 2.88 8 T-2 50.77 Ontrak 8114 8 T-2 69.44 Modular Stab 121/4 2.88 8 T-2 75.22 BCPM 8114 2.88 8 T-2 86.53 Top Stop Sub 9 112 3.00 66/8 Reg 87.98 Filter Sub 8 65/8 Reg 91.01 Orienting Sub 8 3.00 6 518 Reg 93.10 Drill Collar - Non Mag 8 6 518 Reg 123.04 Drill Collar - Non Mag 8 6 518 Reg 152.01 Drill Collar- Non Mag 8 65/8 Reg 182.32 XO Sub 8 3.50 41/2 NC 50 185.72 3 HWDP 5 3.00 41/2 NC 50 277.78 Drilling Jars - Hydraulic 6 114 2.75 4 112 NC 50 307.32 2 HWDP 5 3.00 41/2 NC 50 369.04 52 Drill Pipe 1 5 4.28 41/2 NC 50 1 2,021.00 Drilling Parameters F)ow Rate startDepth End Depth Sliding (gpm) WOB RPM Pu St -M Drii Strwl I WstrWt (We) (ftKB) Cum Depth (9) Cum 0h11 Tme(no Tone Mr) (gpm) (10001bQ (rpm) 9PP jpl1) (1000" (,=bQ (100MbQ OR a"Tq Drill Tq 1,620.0 2,021.0 1,906.00 13.90 1.40 850 U1 70 2,450.0 122 121 120 2.5 5.5 2,021.0 2.021.0 1,906.00 13.90 Wellbores Wellbore Name Wellbore API/UWI MT6-08 501032077200 Sectbn Des Size (in) Act Top MKe) Aa BM (WB) Start Data End Date CONDI 42 36.6 115.0 2162018 21612018 SURFAC 16 115.0 2,021.0 7/162018 7/192018 INTRMi 12114 2,021.0 10,330.0 7/192018 7/282018 Page 2/3 ReportPrinted: 9/1112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 4 Report Date: 7117/2018 Rig: DOYON 19 Sadden Dea Size (in) Act Top (ftKB) I Act Bim (RKB) Staff Data End Date INTRM2 83/4 10,328.0 12,469.5 8/9/2018 8/19120 8 PRODt 6 12.469.5 21,102.0 8/19/2018 9/5/2018 Survey Data MD (N(B) Ind (°) Azm (°) WD (MB) I VS (fl) NS dt) EW (fll OLS (°Haan) 1,714.01 15.74 330.77 1,702.21 132.62 117.49 -61.53 1.52 1,807.87 17.54 330.52 1,792.14 159.49 140.91 -74.71 1.92 1,901.92 18.98 329.99 1,881.45 188.95 166.49 -89.34 1.54 1,955.79 1948. 330.04 1,932.31 206.68 181.86 -98.20 0.93 Page 3/3 Report Printed: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) IT MT6-O8 Report Number: 5 =�'Rig: DOYON 19 Report Date: 7/18/2018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKB) End Depth (MB) MT6-08 Development 2.93 5.0 0.00 2,021.0 2,021.0 Actual Start Date 1 Original Spud Date AFE our Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/14/2018 7/16/2018 51.65 51.22 0.43 902018 Last Casing String 13-3/8" Surface, 2,010.6ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE N/U MPD, Katch Kans & flow lines. Test BOPE. M/U 12-1/4" BHA RIH to drill out. FIT. Drill ahead. Last 24hr Summary Cont. to run casing & land on hanger @ 2,010'. Circ & cord for cement job. Cement casing as per SLB. CIP @ 11:00 Hrs. N/D riser & annular. N/U BOPE & MPD. General RemarksWeather Head Count No AIS. Camp on High Line @ CD5. Rig on generators as 05:30 7/9/18Hrs. Rain, 47°F, Wind W 13 mph, tis 6 m 150.0 Supervisor TO. Rob Rein ardt,Rig Supervisor - Rig Supervisor Adam Dorr,Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer - Rig Engineer Tom Polasek,DNiing Engineer Drilling Engineer Adam KIem,Compietions Engineer Completions Engineer Time Log Time P Start -nine Entl Time Dur(lir) Phase On code ActivityC a -Tx TIDI Code Trbi Class Start Depth(Weir Ehd Depth (19(8) Operat. 0000 01:45 1.75 SURFAC CASING PUTB P 1,425.0 1,971.0 RIH w/13-3/8" 68# L-80 TXP & Hyd 563 casing f/1,425'to 1,971'. PU wt 160k/SO wt 150k 01:45 02:30 0.75 SURFAC CASING HOSO P 1,971.0 2,010.0 M/U hanger & landing it. Land casing on hanger @ 2,010.6 02:30 05:00 2.50 SURFAC CEMENT CIRC P 2,010.0 2,010.0 Cite Gond mud for camentjob. Stage pumps up to 8 bpm 1180 psi. Reciprocate pipe. PU wt 165 k / SO wt 152 k. SIMOPS - R/D casing running tools & equipment. 05:00 05:15 0.25 SURFAC CEMENT RURD P 2,010.0 2,010.0 B/D top drive. R/U cement lines to Volant. 05:15 07:15 2.00 SURFAC CEMENT CIRC P 2,010.0 2,010.0 Cont. to circ & wind mud for cement job thru cement linesw/8 bpm / 370 psi. Reciprocate pipe. PU wt 165 k / SO wt 152 k. PJSM on cementing. 07:15 11:00 3.75 SURFAC CEMENT CMNT P 2,010.0 0.0 Rig load 42.5 bbis nut plug marker in pipe. Dowell pump 1 bbis H2O & PT to 3500 psi (good). Dowell pump 105.7 bible 10.3 ppg mud push w/4.5 bpm / 110 psi. Shut down & drop bottom plug.Dowell pump 324.8 bbis 11.0 ppg 1.92 ft3/sx yield LiteCRETE lead cement, 72.7 bbis 15.8 ppg 1.16 113/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace w/268.8 bbls 12667 stks 9.8 ppg DnIlPlex w/8 bpm / 670 psi. Observe hole trying to pack off. Reduce pumps to 4 bpm / 440 psi. Bump plug, pressure 500 psi over to 1000 psi for 5 min. Check floats / F/C good. CIP @ 11:00 Hrs. Calculate 55 bbls good cement to surface & 145 bbis cement lost down hole. Latest BOP Test Data Date I Com Page 113 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-O8 Report Number: 5 Report Date: 7/18/2018 DOYON 19 Time Log Tme P Stan Time EmInme Durfta) Phase Go, Code Activity Code -T:X Trbl Cade Tri Start Depth(fll End Dal (l Operation 11:00 11:30 0.50 SURFAC CEMENT WWWH P 0.0 0.0 Flush riser& annular with black 1 water. Function annular & flush second time. 11:30 12:30 1.00 SURFAC CEMENT RURD P 0.0 0.0 RID cement lines. B/D same. RID volant & LID same. B/O landing it & LID same. 12:30 15:15 2.75 SURFAC CEMENT NUND P 0.0 0.0 Remove hole fill & bleeder lines. Drain lines. Disconnect Koomy lines. N/D diverter annular & remove from cellar. 15:15 17:45 2.50 SURFAC WHDBOP NUND P 0.0 0.0 Bring well has into cellar N/U well head & test void t/1000 psi f/10 min good. 1745 22:30 4.75 SURFAC WHDBOP NUND P 0.0 0.0 N/U BOPE. Tighten speed head. N/U choke & kill lines under rig floor. BWM on blind rams. Tighten BOPE rams doors. SIMOPS - Clean pits. Load pipe shed w/9-5/8" casing. M/U floor valves & rocket launcher. 2230 0000 1.50 SURFAC WHDBOP MPDA P 1 0.0 0.0 MN MPD equipment. N/U MPD I clamp, orbit valve, flow box. Mud Check Data VPcak Gel n0s) Gel (10m) Gat (30m) HTHP Filtrate Density Temp Satiate, Carr. Type Depth(Wl) Dens ilb/gaq Vias/qq PVCaIc(cP1 QtilttD0e1 gavi m (tr1100M) (1bf/100" Ml (mLl3omin) pH (°F) (%) DRILPLEX 2,021.0 9.90 15.0 19.0 21.0 33.0 48.000 17.5 11.0 68.0 9.5 DRILPLEX 2,021.0 9.90 15.0 18.0 20.0 31.0 47.000 17.5 11.0 70.0 9.5 DRILPLEX 2,021.0 9.90 15.0 20.0 21.0 34.0 52.000 17.5 11.1 73.0 9.5 DRILPLEX 2,021.0 9.95 20.0 21.0 24.0 36.0 41.000 18.0 10.9 67.0 9.5 Injection Fluid Fluid source From Lease (man cast Vendor Man at Number Note Drilling Mud WBM MT6-08 110.0 CDI-01 AES 529666 MT6-08 Source Well Drilling Mud WBM MT6-08 275.0 CD1.01 AES 529662 MT6-08 Source Well Dulling Mud WBM MT6-08 275.0 CD1-01 AES 529664 MT6-08 Source Well Dulling Mud WBM MT6-08 275.0 CDi-01 AES 529663 MT6-OS Source Well Dulling Mud WBM MTS -08 275.0 CD1-01 AES 529665 MT6-08 Source Well Wellbores Wellbore Name Wellbore APIIUWI MT6-OS 501032077200 Section Des Size (m), Act Top (RKB) Act Ban (al(e) Stan Data End Data CONDI 42 36.6 115.0 2/612018 216/2018 SURFAC 16 115.0 2,021.0 7/16/2018 7/19/2018 INTRM1 121/4 2,021.0 10,330.0 7/19/2018 7/28/2018 INTRM2 8 314 10,328.0 12,4159.5 8/9/2018 8/19/2018 PROD1 6 12,469.5 21,102,0 8/19/2018 9/5/2018 'Casing Strings Csg Des I Run Date GD (m) W en (Il Grade Set Dept (aKa) Com 13-3/8" Surface 7/18/2018 133/81 68.00 L-80 2,010.6 16 Centek & 34 Bow Spring Cement Surface Casing Cement - Started @ 7/1812018 Type Wellbore filamented String Cement Evaluation Results Casing MT6-08 13-3/8" Surface, 2,010.6ftK8 55 bbis 11.0 ppg cmnt to surface 145 bbis lost to formation. CIP @ 11:00 Hrs 7118/18 Big p Description Top Depth (ftKB) Bottom Depth (fiKB) Q Pump Final... P Pump Final (psi) 1 Surface Casing Cement 38.0 2,010.6 4 440.0 Flud Class Amount (sacks) Vd Pumped(bbh Dens(lagait YnW(Wtsack) Est Top (i Est Benifft i Lead Cement LiteCRETE 1,040 1 324.8 11.001 1.921 38.0 1 1,510.0 Page 2/3 Report Printed: 911112018 Security Level: AK Development AL N Daily Drilling Report (No Costs) MT6-08 Report Number: 5 Report Date: 7118/2018 Rig: DOYON 19 Fluid Class Amount (sacks) I Vol Pumped (bbl) 1 Dens (Iblgal) I Y.W (fl /sack) Est Top (RKB) EV Bm (hKB) Tail Cement G 3501 72.7 1 15801 1.16 Ii 1,510.0 2,010.6 Page 313 ReportPrinted: 9111/2018 Security Level: AK Development AL Daily Drilling Report (No Costs) MT6-08 ReportNumber: 11 Rig: DOYON 19 Report Date: 7/24/2018 Wellbore Well Type I DFS (days) IDOL (days) Depth Progress (ft) Start Depth (fi I End Depth (ftKB) MT6-08 -Development8.93 11.0 0.00 10,330.0 10,330.0 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/14/2018 7/16/2018 51.65 51.16 0.49 M/2018 Last Casing String 13-3/8" Surface, 2,010.6ftKB Ops and Depth @ Morning Report 24hr Forecast P/U and run 9-5/8" TXP casing @ —2,000' MD. Continue testing with 9-5/8" T.I. P/U and RIH 9-5/8" casing per detail. Circulate and Condition for cement. Last 24hr Summary POOH to 4,650' MD. BROOH to shoe, CBU x 2. POOH & L/D BHA #2. Change upper rams to 9-5/8" SBR, test. R/U to run casing. General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on generators as 05:30 7/9/181-Irs. BO PE Tested Overcast 62°F, Wind S 8 mph, Via 10 mi 52.0 7/19/18. Agencies notified for testing 7/26. Suparvuor Title Andy Marushack,DnlOng Engineer Drilling Engineer Rob Reinhardt Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Tom Polasek,Dnlling Engineer Drilling Engineer Adam KIem,Completions Engineer Completions Engineer Time Log Time P Sortrme End Time Dur(hr) Phase Op Code Acbvity Code -T-X TEl Code Td,10ass Start Deplh(RK5) End DepW(aKe) Operation 00:00 00:15 0.25 INTRMI CASING TRIP P 6,277.0 6,082.0 Continue pulling out of hole on trip tank from 6,277' MD to 6,082' MD. Correct hole fill. 00:15 01:15 1.00 INTRMI CASING CIRC P 6,082.0 5,987.0 Planned circulation, pumped 39.5 bbl HV NP sweep around @ 950 gpm, 3130-2820 psi, adjust rotary RPM from 80-180 as needed for shock/vibratiuon, 6.5-5.5k Tq. P/U=200k, S/0=150k, ROT=160k. Considerable cuttings returns on shakers. 01:15 02:30 1.25 INTRMI CASING TRIP P 5,987.0 4,662.0 Continue POOH on trip tank from 5,987' MD (laying down 12-5/8" Ghost Reamer) to 4,662' MD. Start pulling tight @ 5,388' MD, wiped OK. Observe swabbing. 02:30 03:15 0.75 INTRMI CASING CIRC P 4,662.0 4,567.0 Circulate bottoms up @ 900 gpm, 2480 psi, 120 rpm, 5k Tq. No gas at bottom up. Moderate cuttings returns on shakers. 03:15 12:00 8.75 INTRMI CASING BKRM P 4,567.0 2,140.0 Backream out of hole from 4,567' MD to 2,140' MD @ 900-950 gpm, 2480-2310 psi, 2k-5.5k Tq. Observe minor packing off and pressure torque events, slow pulling speed to 600 fph. Pumped 2 ppg over weighted sweep @ 2,750' MD while back reaming, some larger blocks up to 4" on shakers. Steady smaller cuttings returns, not sticky on shakers to —2,300'. Hole unloaded @ 2,269' MD, siltstone cavings from 2" to 10" steady on all shakers for 45 minutes while backreaming Bland. 12:00 14:30 2.50 INTRMI CASING BKRM P 2,140.0 1,935.0 Continue BROOH from 2,140'to 1,935' MD, 950 gpm, 2300 psi, 1 120 rpm, 1-3k Tq, Latest BOP Test Data Date Com ruest BpPE 25ot3500 for 6110 min', wlq test hnkp valves 1 14 IROP's Choke needle valve Unnar/low Page 1/3 Report Printed: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 ReportNumber: 11 Report Date: 7/24/2018 Rig: DOYON 19 Time Log Time F StaM1 Time Erb Time Cur(ho Phase Op Code Acdv,n, Code -T-X Trbl Code Trbl Class Stan DepM (flKa) EM Dodds (RKS) Cperaoon 14:30 15:30 1.00 INTRMI CASING CIRC P 1,935.0 1,935.0 Circulate casing clean, pump 40 bbl weighted nut plug sweep, followed by second sweep @ 750 gpm, 1400 psi, 100 rpm, 1-2k Tq. 15:30 15:45 0.25 INTRMI CASING OWFF P 1,935.0 1,935.0 Monitor well for flow, static with slight drop in 15 min. 15:45 16:30 0.75 INTRMI CASING TRIP P 1,935.0 619.0 POOH on elevators from 1,935' MD to HWDP @ 619' MD. P/U=90k, Correct hole fill. 16:30 16:45 0.25 INTRMI CASING OWFF P 619.0 619.0 Monitor well for flow @HWDP, static. SIMOPS- PJSM on LID BHA. 16:45 1900 2.25 INTRMI CASING SHAH P 619.0 0.0 Rack back 4 stands HWDP with jars, lay down remaining BHA. 19:00 19:30 0.50 INTRMI CASING BHAH P 0.0 0.0 Remove BHA Components from rig floor, clean and Gear. 19:30 20:30 1.00 INTRMI CASING RURD P 0.0 0.0 Mobilize casing tools and equipment to ng floor. SIMOPS- RAJ Volant CRT. 20:30 22:00 1.50 INTRMI CASING BOPE P 0.0 0.0 PJSM, change upper pipe rams from 3'f." x 6" VBR to 9-5/8" SBR. SIMOPS- Continue to ng up casing equipment. 22:00 22:45 0.75 INTRMI CASING BOPE P 0.0 0.0 Pull wear bushing and set test plug. Observe trip nipple <V from bottom of master bushing due ng settling. 22:45 23:00 0.25 INTRMI CASING BOPE P 0.0 0.0 Pull trip nipple. 23:00 23:30 0.50 INTRMI CASING BOPE P 0.0 0.0 Set 9-5/8" test joint, R/U and flood stack and lines for testing. SIMOPS, cut down 4" from trip nipple. 2330 00:00 0.50 INTRMI CASING BOPE P 0.0 0.0 Test annular preventer with 9-5/8" test joint to 250 psi for min, 25400 psi for 10 min charted. Mud Check Data W Cak Gel(10s) Gel (10m) Der(Wrn) HTHP hils.te Density Temp Soeds,Cem. Type DepM.(We, Dens(Wsl) Voi(slgp WCak(cF) (Ibfflo ) OVIIODR) (Ibf/100fi') (IENYOD11 MST.(lb2b) (mWOmin) pH ('F) (%) Low Solids 10,330.0 10.00 49 9.0 34.0 17.0 20.0 23.009 17.0 0.0 9.6 112.0 10.5 Non- Dispersed Low Solids 10,330.0 10.00 48 8.0 33.0 17.0 19.0 22.009 16.5 0.0 9.6 111.0 10.5 Non- Dispersed Low Solids 10,330.0 10.00 49 8.0 34.0 18.0 20.0 22.009 15.0 0.0 9.6 118.0 11.0 Non- Dispersed Low Solids 10,330.0 10.10 48 9.0 33.0 18.0 20.0 23.009 14.8 0.0 9.7 105.0 10.5 Non- Dispersed Injection Fluid Flod I Source From 4eese(bbp Desl I Vendor Manifest Number I Note Drilling Mud WBM MTS-08 275.0 (;D1-01 AES 529699 MT6-08 Source Well Drilling Mud WBM MT6-08 275.0 CD1-01 AES 529700 MT6-08 Source Well Drill Strings: BHA No. 2 - 12-114" AutoTrack BHA I Bit Run No. 2 - 12114in, DD605SX, 5279054 Depth In (M(S) Depth Out (nKB) TFA'Incl Noz) (In') Nozzles (1132") IADC Bil Dull String Wt (10001bfi 2,021.0 10,330.0 1.02 12/12/12/15!15/15/15 1-1-WT-A-X-1-NO-TD 233 Page 2/3 ReportPrinted: 9111/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 11 Rig: DOYON 19 Report Date: 7/24/2018 Drill String Components Jls Item Des OD (in) ID (in) Top Conn Sz(n) Top Thread Cum Len (11) AutoTrak Steering head 11.86 2.48 9 1/2 T2 9.45 Flex sub w/Stab 12 114 3.12 9 12 T2 20.96 NM X/O sub 91/2 3.50 81/4 T2 24.00 OnTrak - MWD 81/4 2.75 81/4 T2 42.40 Mod stab 121/4 2.88 81/4 T2 46.54 BCPM 81/4 2.88 8114 T2 58.22 Stop sub 81/4 3.13 6518 Reg 60.59 Filter 8 3.00 65/8 Reg 63,62 Float 8 3.00 65/8 Reg 65.47 Float 8 3.00 65/8 Reg 67.38 3 NMDC 8 2.75 65/8 Reg 156.60 X/O sub 8 2.75 4112 IF 160.00 12 HWDP 5 3.00 41/2 IF 528.07 Jars 6.258 2.75 41/2 IF 557.61 2 HWDP 5 3.00 41/2 IF 619.33 168 Drill Pipe 5 4.28 41/2 IF 5,921.67 Reamer 10518 2.75 41/2 IF 5,928.79 140 Drill Pipe 1 5 4.28 4 1/2 IF 10,330.00 Drilling Parameters Fbw Ra e Sort Depth End Depth Sliding (gpm)WOB RPM Pu Sr Wt Drill Srm sosrm (ftKB) (RKBj Cum Dept, (ft) Cum Dnli Time(h4 Time (M) Op.)(1000Ibf) (-:z SEP (p,,) (10001bn (10001bq (10WIM OR Bun Tq DrMTq 10,330.0 10,3 0.01 8,309.001 66.301 1 Wellbores Wellbore Name Wellbore API/UWI MT6-08 501032077200 Section Des Size (m) Act Top (hKB) Act Btm (ftKB) Stan Date End Daze CONDI 42 36.6 115..0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,021.0 7/16/2018 7/192018 INTRMI 121/4 2,021,0 10.330.0 7/19/2018 728/2018 INTRM2 83/4 10,328.0 12,469.5 8/9/2018 8/19/2018 PROD1 6 12,469.5 21,102.0 8/19/2018 915/2018 Page 3/3 Report Printed: 9/11/2018 zi Security Level: AK Development AL Daily Drilling Report (No Costs) MT6-08 Report Number: 12 Rig: DOYON 19 Report Date: 7/25/2018 Wellbore Well Type DFS (days) DOL (days) Depth Progress (k) Start Depth (ftKB) End Depth (fiKB) MT6-08 Development 9.93 12.0 0.00 10,330.0 10,330.0 Actual Start Date Original Spud Date I AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/14/2018 7/16/2018 151.65 52.16 -0.51 9/412018 Lest Casing String 13-3/8" Surface, 2,010.6ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating and Conditioning for cement job, rasing landed 04:15 bra @ 10,317' MD. Run casing to 10,317', C&C for cement, pump Intermediate 1 cement job per program. Set and test packoff. F/C, nipple down and install 7" casing spool. N/U BOP, change rams and test BOPE. Last 24hr Summary Continue testing with 9-5/8" T.I. RID and RIH 9-5/8" casing per detail to 8,846' MD, circulating as needed. General Remarks Weather Head Count No AIS. Camp on High Line @ CD5. Rig on generators as 05:30 7/9/181-Irs. BOPE Tested Overcast, 62°F, Wind S 8 mph, Vis 10 mi .53.0 7/19/18. AOGCC updated for testing 726. Supervisor Title Rick Bjormus,Rig Supervisor Rig Supervisor Rob Reinhardt,Rig Supervisor Rig Supervisor Diana Guzman,Rig Engineer Rig Engineer Andy Mamshack, Drilling Engineer Drilling Engineer Tom Polasek,Dnlling Engineer Drilling Engineer Adam k3em,Completions Engineer Completions Engineer Time Log Time P Sart Lme End-rime Cahn Phase Op Code. Aarvity Code -FX Trbl Code Trbi Class Sart depth (MBI End Deph(ftKB) Operahan 0000 0030 0.50 INTRMI CASING BOPE P 0.0 0.0 Continue testing with 9-5/8" test joint, Test Upper SBR's to 250 psi for 5 min, 3500 psi for 10 minutes charted. Rig down test equipment. 00:30 01:00 0.50 INTRMI CASING RURD P 0.0 0.0 Pull test plug, set thin wall wear ring. 01:00 01:45 0.75 INTRMI CASING RURD P 0.0 0.0 Rig up to run 9-5/8" casing, verify pipe Count and centralizers / pup/hanger. 0145 0200 0.25 INTRMI CASING SFTY P 0.0 0.0 PJSM on running 9-5/8" Casing. 02:00 09.00 7.00 INTRMI CASING PUTB P 0.0 4,087.0 Make up shoe track, Bakerlock to pin of #4. Pump through shoe track and check floats, good. Continue PIU and RIH with 9-5/8" 40 # TXP-HS TN80 and TXP L80 Casing to 4,087' MD per detail (103 jts in hole) Taking weight -50k. P/U=190k, S/0=170k. 09:00 10:30 1.50 INTRMI CASING CIRC P 4,087.0 4,087.0 Circulate and condition mud, 2.5 bpm-7 bpm, 180-230 psi. Some slight packing off. Pumped 5200 stks, (2 bottoms up) 10.1+ ppg max mud weight out. 10:30 12:00 1.50 INTRMI CASING PUTB P 4,087.0 4,880.0 Continue RIH from 4,087' MD to 4,880' MD per detail. S/0= 182k. 12:00 14:00 2.00 INTRMI CASING PUTB P 4,880.0 5,921.0 Continue RIH from 4,880' MD to 5,921' MD per detail. S/0= 175k. Observe loss of 25-30k SOW. 14:00 15:00 1.00 INTRMI CASING CIRC P 5,921.0 5,961.0 Break circulation @ 1 bpm, 480 psi, stage up to 3.5 bpm, wash down joint to 5,961' MD pumped 100 bbl. 15:00 17:00 2.00 INTRMI CASING PUTB P 5,961.0 7,043.0 Continue RIH from 5,961' MD to 7,043' MD per detail. S/0= 175k. Observe loss of 30-35k SOW. Latest BOP Test Data Date Can 7/19/2nlA ITP.%t RC)PF 9RI11351710 for 5/10 min'q wM test to nts Annular 4" ner= Choke valmes I - 14 IROP's Choke needle valve Unnedlow Page 1/2 ReportPrinted: 9/11/2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 12 Report Date: 712512018 Rig: DOYON 19 Time Log Time P Start Time Ertl Tan. Dur(hr) Phase Op COG. AMIFCade -T-% T@ICode Trd Cfess Stat Dapth(flKB) Entl Depth(ItKB) operation 17:00 20:00 3.00 INTRMI CASING CIRC P 7,043.0 7,043.0 Break circulation @ 1 bpm, 630 psi, stage up to 8 bpm. Heaviest mud weight out 11.0+, circulate until mud weight 10.1+out Pumped 800 bbl, 1.75 bottoms up. No recordable losses during circulation. 20:00 2300 3.00 INTRMI CASING PUTB P 7,043.0 8,806.0 Continue RIH from 7,043' MD to 8,806' MD per detail. S10= 150k. Observe loss of 30-35k SOW. Getting good displacement during rasing run. Calculated displacement for trip=132 bbl, Actual Displacement--110 bbl. 23:00 00:00 1.00 INTRMI CASING CIRC P 8,806.0 8,846.0 Break circulation @ 1 bpm, 880 psi, stage up to 4 bpm, wash down joint to 8,846' MD pumped 120 bbl. No recordable losses during circulation. Mud Check Data �cak Gel (10s) Gel(ift) Gel(W.) HTHPFTnde Density Temp Sads.CGrc Type Deplh(W13) DensablgBl) Ms(slgp WCak(cP) (Ibftloof) (Ibrl100M1q (Por/100fM (Ibfl100X') MST Ob ii (mL sfflm pH CH (%) Low Solids 10,330.0 10.05 50 9.0 28.0 14.0 16.0 17.007 17.0 0.0 9.5 86.0 10.5 Non- Dispersed Low Solids 10,330.0 10.00 53 11.0 30.0 16.0 18.0 21.009 17.0 0.0 9.5 87.0 10.5 Non- Dispersed Low Solids 10,330.0 10.05 56 11.0. 33.0 18.0 22.0 25.010 17.0 0.0 9.5 98.0 10.5 Non- Dispersed Low Solids 10,330.0 10.00 53 10.0 33.0 17.0 20.0 23.009 17.0 0.0 9.6 105.0 10.5 Non- Dispersed Injection Fluid Had Source From Lease (bhp Dest Al VeMor Manitas[Number Note Dolling Mud WBM MT6-08 275.0 CD' AES 518051 MT6-08 Source Well Wellbores Wellbore Name Wellbore API/UWI MT6-08 501032077200 Section Das Siae (in) Act Top (RKS) Ad SM (dKB} Slad Dale End Date CONDI 42 36.6 115.0 2/6/2018 2/6/2018 SURFAC 16 115.0 2,021.0 7/16/2018 7/1912018 INTRMI 121/4 2,021.0 10,330.0 7/19/2018 7/28/2018 INTRM2 8314 10,328.0 12,469.5 8/9/2018 8/19/2018 PROD1 6 12,469.5 21,102.0 8/1912018 9/5/2018 Page 2/2 ReportPrinted: 9/112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 13 Rig: DOYON 19 Report Date: 7/26/2018 Wellbore Well TypeDFS (days) DOL (days) Depth Progress (ft) Start Depth (ftKB) End Depth (ftKB) .MT6-08 Development 10.93 13.0 0.00 10,330.0 10,330.0 Actual Start Date Original Spud Date AFE our Total (days) I Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 7/14/2018 7/16/2018 51.65 152.59 -0.94 9/5/2018 Last Casing String 9-5/8" Intermediate 1, 10,317.7ftKB Ops and Depth @ Morning Report 24hr Forecast Changing upper rams on BOP stack to 41%" x 7" VBR, SIMOPS- Flush and FP annulus Install 7" casing spool, test packoff top. N/U BOP, set test plug. (SIMOPS-Flush and FP annulus.) Change rams and test BOPE. Pull storm packer. Set wear ring, M/U 8-3/4" BHA#3, RIH. Last 24hr Summary Run casing to 10,317', C&C for cement, pump Intermediate 1 cement job per program, plug did not bump, floats held. Set and test packoff. F/C, set'L' Stonn packer.. N/D BOPE, prep to install 7" casing spool. General Remarks Weather Head Count No AIS. Camp on High Line @ COS. Rig on generators as 05:30 7/9/18Hrs. BOPE Tested Light Rain, 40"17, Wind NE 10 mph, WC 34, Vis 55.0 7/19/18. Daily cast reflects 9-5/8" casing tangibles and cement/ service. 10m Superwsor Tae Rick Bjorhus,Rig Supervisor Rig Supervisor Rob Reinhardt,Rig Supervisor Rig Supervisor Diana Guzman.Rig Engineer Rig Engineer Andy Marushack, Drilling Engineer Drilling Engineer Tom Polasek,Driliing Engineer Drilling Engineer Adam Klem,Completions Engineer Completions Engineer Time Log Time Seen Tme Erie Time Dur(hn Phase op Code Activity Code -T-X TMi CM TMIClass Start Depro(ftKB) Entl Depth(ftKS) Operation 00:00 03:30 3.50 INTRMI CASING PUTS P 8,846.0 10,279.0 Continue PIU and RIH with 9-5/8" 40 # TXP L80, pup and XO to H563 casing from 8,846' MD to 10,279' MD per detail. 254 jts in hole plus XO and pup. 03:30 04:15 0.75 INTRMI CASING HOSO P 10,279.0 10,317.0 Make up hanger and landing joint, wash down @.5 bpm, 980 ICP. Land hanger and stay landed. (Note, very tight tolerances through stack and thin wall wear ring, Reciprocation would be very risky) Final SOW=190k. 04:15 09:15 5.00 INTRMI CEMENT CIRC P 10,317.0 10,317.0 Circulate and condition mud, stage up from .5 bpm to 4.5 bpm, 980 psi to 500 psi, Stay at 4.5 bpm until first wave of heavy mud (11.5+) out of hole @ 3,600 stks. Stage up to 6 mpm until second wave of heavy mud coming out (11.7+), separated by 120 bbl clean mud pumped at 8,800' while RIH. Stage up to 8 bpm, 460 psi FCR. 10.0 ppg in, 10.1 ppg out, total 3 x bottoms up pumped. 09:15 10:15 1.00 INTRMI CEMENT RURD P 10,317.0 10,317.0 Shutdown, OWFF static. Blow down top drive, remove mud saver valve from Volant CRT. Rig up cement hose and 1502 equipment to cement line. 10:15 10:45 0.50 INTRMI CEMENT CIRC P 10,317.0 10,317.0 Break circulation through cement hose, 8 bpm 650 psi. SIMOPS- PJSM on cementing 9- 5/8" casing. Latest BOP Test Data Data Cam 7/1-91201A I Test ROPE ?�17)13.Sn() for 5/1fl in n'q w/9 test inints A nular 4" nemrz Choke vnlveq 1 - 14 IROP'% Choke needle valve Unnp. Page 113 ReportPrinted: 9MI2018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 13 Rig: DOYON 19 Report Date: 7/26/2018 Time Log Tlme P Start Time E,wrme Dur(hr) Phase Op Code AW tfCede -T-X TNA Code Tti Gass Slen Depth (ftB) End Depih(ftKB) Opere. 1045 1200 1.25 INTRM7 CEMENT CMNT P 10,317.0 10,317.0 SLB flood lines with 5 bbl water. Pressure test to 3500 psi, good. SLB pumped 58.5 bbl 12.5 ppg mud push. Shut down and drop bottom plug. Mix and pump 39 bbl 12.2 ppg Lead cement @ 3.4- 4.2 bpm. Swap to tail, begin pumping 15.8 ppg tail. 12:00 12:30 0.50 INTRMI CEMENT CMNT P 10,317.0 10,317.0 Continue pumping 15.8 ppg Tail cement, 2.9-3.4 bpm @ 473 psi (46 bbl). Shut down, drop top plug. SLB kick out with 20 bbl water. 12:30 14:00 1.50 INTRMI CEMENT CMNT P 10,317.0 10,317.0 Rig displace cement with 10.0 ppg LSND @ 8 bpm, ICP=430 psi, FCP @ 8 bpm=730 psi. Slowed pump to 3 bpm, 540 psi @ 730 bbl away. Continue displacement to 7603 strokes, plug did not bump. Shut down. 1400 1430 0.50 INTRMI CEMENT CMNT P 10,317.0 10,317.0 Hold 540 psi for 10 minutes, pumped final strokes to max 7607 total @ .3 bpm, 600 psi. Plug not bumped. Hold 600 psi for 10 minutes. Bleed off and check floats, floats good. CIP @ 4:17 hrs. 14:30 1530 1.00 INTRMI CEMENT RURD P 10,317.0 0.0 Rig down Volant CRT, lay down landing joint. 15:30 16:00 0.50 INTRMI CEMENT RURD P 0.0 0.0 Pull wear bushing. 16:00 17:30 1.50 INTRMI CEMENT WWSP P 0.0 0.0 Set 9-518" packoff and test to 5000 psi for 10 minutes, CPAI witnessed - good. 17:30 19:00 1.50 INTRMI CEMENT TRIP T Cement - Other 0.0 940.0 Mobilize storm packer to set due Primary cement top plug not bumped. SIMOPS- RIH with stack washer, 3 stands 5" HWDP, 7 stands 5" DP to 940' MD. 20k hang off weight Make up Type'L' Retrievomatic Service Packer to stump. 19:00 20:30 1.50 INTRM1 CEMENT WAIT T Waking Wait on 940.0 940.0 Standby for delivery of Twin Offsite Thread Safety joint and Equipment Rotational Equalization Valve from CD1, not delivered with Storm Packer. 20:30 21:00 0.50 INTRMI CEMENT MPSP T Cement- Other 940.0 0.0 Make up twin thread safety joint Primary and equalization valve to packer, RIH with packer to 1,048' MD bullnose depth, Packer COE @ 102' MD, 82k SOW. Set packer per Baker rep with 1/4 LH tum. Set down to block weight. Right hand tum 13 turns to release, POOH. Top of packer stump @ 92.11' MD 21 00 21 30 0.50 INTRMI CEMENT PRTS T Cement - Other 0.0 0.0 Close blind rams and test packer I Primary 1 to 1000 psi for 5 minutes, 0.6 bbl pumped. Bleed off and rig down. Page 213 ReportPrinted: 911112018 Security Level: AK Development Daily Drilling Report (No Costs) MT6-08 Report Number: 13 Rig: DOYON 19 Report Date: 7/26/2018 Time Log Time P Start Time End Time Our (M1r) PM1ase op Code Aclrviy Cade -T-X TM Cotle Trbl Glass Start DepN (M1Ka) EM DepN (flKB) OpefeGon 21:30 22:30 1.00 INTRMI CEMENT NUND P 0.0 0.0 PJSM, Drain stack, pull mouse hole, pull trip nipple and flow box for N/D. SIMOPS- Change out solenoid valves on top drive. 2230 23:30 1.00 INTRMI CEMENT NUND P 0.0 0.0 N/D BOPE and tubing spool. SIMOPS- Change out solenoid valves on top drive. 23:30 00:00 0.50 INTRMI CEMENT NUND P 0.0 0.0 Prep for install T' casing spool. SIMOPS- Change out solenoid valves on top drive. Mud Check Data VPCek Gel(tos) Gel(10m) Gel (sash) HTHPFilinne Densiy Temp Solid ort. Type DepM(e%B) Dens(@/gap Vis(s/ary [W Cat(CP) (IU/100fM Of/100" (WHtOo" (@N/100" MST(Po@hfl (MI-Mmin) pH ("F) (%) Low Solids 10,330.0 10.00 44 9.0 22.0 11.0 13.0 14.006 12.0 0.0 9.4 83.0 10.0 Non - Dispersed Low Solids 10,330.0 10.00 44 8.0 23.0 11.0 13.0 14.006 12.0 0.0 9.4 83.0 10.0 Non - Dispersed Low Solids 10,330.0 10.00 42 7.0 19.0 - 8.0 10.0 11.005 12.5 0.0 9.4 86.0 10.0 Non - Dispersed Low Solids 10,330.0 10.00 53 11.0 30.0 16.0 18.0 21.009 15.0 0.0 9.5 81.0 10.5 Non - Dispersed .Injection Fluid Fluid Source From Lease (bbl) I Dost f Vendor I Mannas/Number Note Drilling Mud WBM MT6-08 275.0 CD1-01 JALS 1518053 1 MT6-08 Source Well Interval Problems Start Dale Start Depih(ftKi End Depth(RKB) Trouble Code Trouble Cosa Wellbore 7/26/2018 10,330.0 10,330.0 Cement -Primary Other MT6-08 7/26/2018 10,330.0 10,330.0 Waiting Wait on Offsite Equipment MT6-08 Wellbores Wellbore Name Wellbore API/UWI MT6-08 501032077200 Se diion Des Size 00 Ad Top (WB) Ad Ban (WB) SW Date End Date COND1 42 36.6 - 115.0 278/2018 2/6/2018 SURFAC 16 115.0 2.021.0 7/16/2018 7M9/2018 INTRMI 12114 2,021.0 10,330.0 7/19/2018 7/28/2018 INTRM2 83/4 10,328.0 12,469.5 879/2018 8/19/2018 PRODI 6 12,469.5 21,102.0 8/19/2018 91512018 Casing Strings Csg Des Run Date I DD (in) IW enlbffldl Grade I Set Depgt (flKB) I Com 9-5/8" Intermediate 1 17T2612018 1 95/81 40.00 1 L-80 1 10,317.7 115 Centek 8 25 Bow spring cement Intermediate Casing Cement - Started @ 7/26/2018 Type Wellbore Cemented String "1: - r. ":;^"'"' Cement Evaluation Results Casing MT6-OS 9.5/8" intermediate 1, 10,317c7�f( ?"-; '., Full returns Sig 7r Description Top Depth (ftKB) Bottom Depth (ftKB) 10 Pump Final... P Pump Final (psi) 1 Intermediate Casing Cement 9,330.0 110,330.0 18 600.0 Fkrb I Class I Amcua(sai I VolPranped(bbp Dens(eigra. Wrslrl (fi'hatlr) Est Tap (lfKSl sets" OWE) Intermediate Lead Cement G 100 39.0 12.20 2.31 9,330.0 9,830.0 Intermediate Tail Cement G 222 48.0 15.80 1 1.16 1 9,630.0 1 10,330.0 Page 313 Report Printed: 9 /1112 01 8 a , Cement Detail Report MT6-08 String: Surface Casing Cement Job: DRILLING ORIGINAL, 71141201812:00 Cement Details Description Surface Casing Cement Cementing Start Date 7118/2018 07:15 Cementing End Date 17/18120 1 /18/2018 11:00 Wellbore Name MT6-08 Comment Cement Stages Stage # 1 Description Surface Casing Cement Objective Top Depth (ftKB) Cement Surface Casing 38.0 Bottom Depth 2,010.6 (ftKB) Full Retum?V051. No l Cement... 55.0 Top Plug? Yes Bon Plug? Yes Q Pump Init (bblim... 8 IQ Pump Final (bell... IQ 14 Pump Avg (bb0... 6 P Pump Final (psl) 440.0 P Plug Bump (psi) 1,000.0 Recip? Yes Stroke (ft) 20.00 Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 12 114 Comment 55 bbls good cement to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 38.0 Est Elm (ftKB) 1,510.0 Amount (sacks) 1,040 Class Volume LiteCRETE Pumped (bbl) 324.8 Yield (fPisack) 1.92 Mix H2O Ratio (galisa... 6.88 Free Water (%) 1 Density (Ib/gal) 11.00 1258,(000 Plastic Viscosity (cP) Thickening Time (hr) 4.40 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,510.0 I Eat Eon (ftKB) 2,010.6 Amount (sacks) 350 Class Volume G 72.7 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... 5. Free Water (%) 1 Density (ib/gal) 15.80 145,000.0 Plastic Viscosity (0) Thickening Time (hr) CmprStr 4.01 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 9111/2018 Cement Detail Report MT6-08 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 7/14/201812:00 Gement Details Description Intermediate Casing Cement Cementing Start Date 7/26/2018 10:30 Cementing End Date 7/26/2018 14:15 Wellbore Name MT6-08 Comment Full returns through job, plug did not bump, floats held. Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Top Depth (ftKB) Cement Intennediate 9,330.0 casing Bottom Depth (ftKB) 10,330.0 Full Return? Yes Vol Cement... Top Plug? Yes But Plug? Yes O Pump [nit (bbllm... 3 IQ Pump Final (bbll... 181600.0 O Pump Avg (bbU... P Pump Final (psi) P Plug Bump (psi) Recip? Na Stroke (ft) Related? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Plug did not bump, floats held. Cement Fluids & Additives Fluid Fluid TypeFluid Intermediate Lead Cement Description Estimated Top (ftKB) 9,330.0 Est Btm (ftKB) 9,830.0 Amount (sacks) 100 Class G Volume Pumped (bbl) 39.0 Yield (ft'Isack) 2.31 MIx H2O Ratio (gallsa... 13.02 Free Water (%) Density (Ib/gal) 12.20 Plastic Viscosity (CP) 23.7 Thickening Time (hr) 5.10 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Intermediate Tail Cement Fluid Description Estimated Top (ftKB) 9,830.0 Est Btm (ftKB) 10,330.0 Amount (sacks) 222 Class G Volume Pumped (bbl) 46.0 Yield (fPfsack)Mix 1.16 H2O Ratio (gal/se... 5.06 Free Water (%) 1 Density (lb/gap 15.80 Plastic Viscosity (cP) 129.0 Thickening Time (hr) 15.00 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 911112018 Note to File MT6-05 (PTD 2180450, Sundry 318-395) Greater Moose's Tooth Unit (Lookout Oil Pool) 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 (MT6-05). -- 13-3/8" Surface casing was cemented at to surface successfully. No problems were reported. Approximately 169 bbls of good cement was circulated to surface. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 5/6/2018, the pressure slope rises smoothly with test stopping at 1.5 bbl pumped and 890 psi to yield a 18.1 ppg EMW. The pressure declined slightly from 890 psi to 845 psi (17.6 ppg EMW) during the 10 minute shut in period. The initial FIT indicates that the surface casing shoe is well cemented. -- On the open hole annulus Leak Off Test (LOT) completed at 7921 ft, dated 5/22/2018, the , pressure slope rises sharply and then a sudden sharp drop off at 577 psi at 9.5 bbl pumped to yield a 16.1 ppg EMW. The pressure falls sharply to 380 psi at the end of 12.5 bbl pumped) and then gradually decreased to 345 psi psi (13.8 ppg EMW) during the 10 minute shut in period. The open hole LOT indicates that formations below the surface casing shoe break down at much lower pressures than the cemented surface casing shoe. -- The 9.625" casing was run and successfully cemented with a single stage job at the shoe of 8920 ft. Cement is estimated up to TOC 7921 ft. Cement job with full returns throughout. Did not bump plug. Annular disposal zone estimated from cemented 13-3/8" surface shoe of 2014 ft to the TOC estimated as 7921 ft of the 9.625". --There are multiple wells currently drilled or planned to be drilled within '/ mile radius of MT6- 05 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 MT6-08 is closest, about 87' distant, and all other planned or drilled wells (8) are less than 392 ft. AD is planned for multiple GMT wells similar to the CD5 development plan. CPAI is therefore constructing the MT6 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 September 26, 2018 F:\cdwallace\Documents\Armular Disposal\180926_MT6-05 note to file.doc Note to File GMTU MT6-05 (PTD 218-045) November 6, 2018 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well MT6-05 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well MT6-05. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 13-3/8" surface casing shoe is set in this well at 2,014' measured depth (equivalent to -1,888' true vertical depth subsea'), near the base of a 650 -foot thick interval of claystone and siltstone 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 sandstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining claystone intervals are sufficiently thick and laterally persistent to ensure injected materials remain within the 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 likely lie within a radius of about 160' from the wellbore. However, the injected fluids may reach several nearby wells that have open annuli beneath the surface casing shoe. If injected wastes reach nearby wells, competent surface casing, cement and the surrounding claystone and siltstone confining layers will ensure the injected waste fluids remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from GMTU MT6-05 and 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 MT6-05 lies in the Seabee Formations within Section 6, TION, R3E, Umiat Meridian (UM) and in section 31, TI IN, R3E, UM, which is about 3,400 from the current exterior boundary of the Greater Moose's Tooth Unit. The surface casing shoes of these wells mainly lie between about -1,918' and to -2,000', near the base of a 650 -foot thick interval that is dominated ' Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet of true vertical depth below mean sea level (mean low, low water). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. 2 MT6-03. MT6-03PHI, MT6-08, MT6-08PH 1, Lookout I, and Lookout 2. MT6-05 Annular Disposal Note to File November 6, 2018 Page 2 of 5 by claystone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for fluids disposed in the annulus of the well (see Figure 3, below). In MT6-05, the annulus open to the disposal interval extends downward from the surface casing shoe at -1,882' to the top of cement for the 9-5/8" casing string, which is estimated to be about -6,320'. The portion of the open annulus that will most likely accept the injected waste is a 190 -foot thick interval containing several 1- to 6 -foot thick beds of sandstone and sandy siltstone that lie between -2,005' and -2,183', below the surface casing shoe (see Figures 1 and 2). The aggregate thickness of these thin, potential receptor beds is about 20'. The sandstone and sandy siltstone are separated by siltstone and claystone intervals. Beneath the disposal interval is a thick interval dominated by claystone that is continuous throughout the area. This interval will provide lower confinement for any injected wastes. Figure 1. MT6-05 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 3.) The index map above displays trajectories for all wells currently drilled from the Greater Moose's Tooth Unit MT6 Drill Site. The locations of the surface casing shoes for all well bores are illustrated using green - colored triangles. The calculated top of cement for MT6-05 production casing string is indicated by orange - colored semi -circle. The interval of open annulus in MT6-05 is represented by the yellow line. Two wells are currently open to these same strata within the '/4 -mile radius area of review: MT6-03 and MT6-08. Figure 2, below, presents a southeast -trending structural cross-section view of MT6-05 and nearby wells Lookout I (located 1.5 miles to the northwest) and the pilot hole for well MT6-03 (labeled "MT6-03PH1", MT6-050 LOOKOU- C 26 0 MT6-OSL1 3 � C d N MT6-08 O O LOOKOUT 1 KEY 0 0.5 m1 Well Paths • Casingshoe— Surface 444A Cement top — Intermed. MITRE 1 • Casing shoe — Intermed. Annulus—Open Interval Figure 1. MT6-05 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 3.) The index map above displays trajectories for all wells currently drilled from the Greater Moose's Tooth Unit MT6 Drill Site. The locations of the surface casing shoes for all well bores are illustrated using green - colored triangles. The calculated top of cement for MT6-05 production casing string is indicated by orange - colored semi -circle. The interval of open annulus in MT6-05 is represented by the yellow line. Two wells are currently open to these same strata within the '/4 -mile radius area of review: MT6-03 and MT6-08. Figure 2, below, presents a southeast -trending structural cross-section view of MT6-05 and nearby wells Lookout I (located 1.5 miles to the northwest) and the pilot hole for well MT6-03 (labeled "MT6-03PH1", I MT6-05 Annular Disposal November 6, 2018 Note to File Page 3 of 5 and located 0.1 miles to the southeast), which were logged to the ground surface. Resistivity measurements suggest that the base of permafrost occurs at roughly -920' in the MT6 Drill Site area, which is about 1,085' above the top of the likely disposal injection interval. 50,O)Zb]SBOU 1.6 mpr 5mbSZOT16D 0., mien 50y�1M'IO NW 0100]0 - - nFbaeb -- — -- z,bo,b, SE OONOOOFHKLIFSN.0.4KMI FW CCNOCORIILLPS OOHOLO%IILLS9 LOOKOUT, INN 3171 LIN LR 31M 326 FHLWFNM1 0N -R Se>, FEL 'Ni F16. 31N FEL 1WP'. 11 N-ibpe:Y E.Sec 36 TWP: ib N-HeryeAESecb TWP: 16 N-gFry9:3 E-Swb ILI 3 r A- 2__ 5 �1 r -----pennafn stBa a 1 ------------------- I y - - Confining In ervals ,1313/8" Casing Shoe ..I .:tea 2,014'MD � -1,882' NDSS)_ _-_-_ L Likely Injecti n IntekvaI Y I Confining In rva/s� J. - 1 � .J Figure 2. MT6-05 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) Annular disposal in MT6-05 will not impact any commercial oil or gas accumulations. A mud log recorded in the pilot hole for nearby well MT6-03 well indicates the likely disposal injection interval contains minor amounts of gas that is predominantly methane. The shallowest oil indicator recorded while drilling the pilot hole for MT6-03 (the nearest mud -logged well) is at -2,760', which is about 580 vertical feet below the base of the likely injection interval. The mud logging geologists described this oil indicator as slow, pale, MT6-05 Annular Disposal Note to File November 6, 2018 Page 4 of 5 straw-colored solvent cut with no associated oil staining. This description suggests the presence of only trace quantities of oil at that depth. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the affected area of the Lookout Oil Pool." This is correct: Conclusion 6 of Area Injection Order No. 40—which governs the Lookout Oil Pool—states that there are no freshwater aquifers within the Affected Area of the Lookout Oil Pool. Figure 3. MT6-05 Area Likely Affected by Annular Injection (Assuming piston -like, radial displacement of 50% of native formation fluids) The gamma ray curve recorded in MT6-05 indicates that about 20 net feet of sandstone and sandy siltstone are present within the likely disposal interval (assuming a gamma ray well log cut-off value of 80 API). Inspection of the neutron and density porosity logs for correlative intervals in the pilot hole for nearby well MT6-03 suggests an average density porosity of about 26 percent at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste material lies within a radius of about 160' from the wellbore, assuming uniform, radial, piston -like displacement of half of the native formation pore fluids (Figure 3). Summary The limited volume of rock that will be affected by this proposed annular disposal program contains predominantly methane gas, is situated beneath about 920' of permafrost, and is bounded above and below by continuous intervals consisting of siltstone and claystone. This disposal interval lies inside the Greater Moose's Tooth Unit, away from any external property lines, so correlative rights are not a concern. There Injected Fluid vs Affected Area Surrounding MT6-05 Wellbore (Assumptions- 26.0'4. porosity, 50% native fluid displacement. aggregate cylinder 20.0' high) 300 — 766' ntlius asawninp 20.0' oT _ n- Injection intarYal a90ayate 3 200 E 0 u A 0 N q too (r /Y Q � 0 10,000 16,000 20,000 25,000 30,000 35.000 Amount of Injected Fluid (barrels) Figure 3. MT6-05 Area Likely Affected by Annular Injection (Assuming piston -like, radial displacement of 50% of native formation fluids) The gamma ray curve recorded in MT6-05 indicates that about 20 net feet of sandstone and sandy siltstone are present within the likely disposal interval (assuming a gamma ray well log cut-off value of 80 API). Inspection of the neutron and density porosity logs for correlative intervals in the pilot hole for nearby well MT6-03 suggests an average density porosity of about 26 percent at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste material lies within a radius of about 160' from the wellbore, assuming uniform, radial, piston -like displacement of half of the native formation pore fluids (Figure 3). Summary The limited volume of rock that will be affected by this proposed annular disposal program contains predominantly methane gas, is situated beneath about 920' of permafrost, and is bounded above and below by continuous intervals consisting of siltstone and claystone. This disposal interval lies inside the Greater Moose's Tooth Unit, away from any external property lines, so correlative rights are not a concern. There MT6-05 Annular Disposal Note to File November 6, 2018 Page 5 of 5 are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within or near the likely disposal injection interval. Although there are nearby wells with annuli that are open beneath the surface -casing shoe, surface casing, good surface -casing cement, and thick overlying siltstone and claystone confining layers should prevent injected fluids from migrating out of the disposal injection interval. I recommend approving the proposed annular disposal operations within GMTU MT6-05 to the limit of 35,00 arrels. Steve Davies Senior Petroleum Geologist r (QA �J °/ �0 ctv r 60i4e!% p/ervd Rixse, Melvin G (DOA) From: Rixse, Melvin G (DOA) Sent: Thursday, November 1, 2018 10:21 AM To: 'Anderson, Nina M' Subject: RE: [EXTERNAL]FW: MT6-05 (PTD 218-045) Annular Disposal Application Pressure Calculations Nina, Thank you for the corrected schematic and the matrix of surface injection pressures for various mud weights. I have included the new schematic and the matrix in the 10-403AD Sundry submitted to AOGCC. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melon Rixse@alaska.gov). From: Anderson, Nina M <Nina.Anderson@conocophillips.com> Sent: Wednesday, October 31, 20184:51 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Noel, Brian <Brian.Noel@conocophillips.com>; Kanady, Randall B <Randall. B. Kanady@conocophiIli ps.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: RE: [EXTERNAL]FW: MT6-05 (PTD 218-045) Annular Disposal Application Pressure Calculations Mel — Attached is the final copy of the corrected annular injection calculations for your files. Please let me know if you need any further questions. Thanks. Diana Guzman / Nina Anderson Alpine Rig Engineers — Doyon 19 Conoco Phillips Alaska Inc. Drilling & Wells Main Office: 907-670-4351 r 2059(aronoccnhillios cam From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Sent: Monday, October 29, 2018 3:29 PM To: Anderson, Nina M <Nma Anderson @Conoco phillips.com> Cc: Noel, Brian<Brian.Noel@conocophillips.com>; Kanady, Randall B <Randall. B.Kanady@conocophillips.com>; Hobbs, Greg S <Gree S Hobbs@conocophillips.com>; Schwartz, Guy L (DOA) «uy Schwartz@alaska.eov> Subject: RE: [EXTERNAL]FW: MT6-05 (PTD 218-045) Annular Disposal Application Pressure Calculations Nina, That works. See Brian and Randy at 10:00 am here. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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(sl. 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 Mel Rixse at (907-793-1231 ) or (Melvin R'xsepw1aska.gov). From: Anderson, Nina M <Nina.Anderson@conocophillips.com> Sent: Monday, October 29, 2018 3:09 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Cc: Noel, Brian<Brian.Noel@conocophillips.com>; Kanady, Randall B <Randall B Kanadv@conocophillips.com>; Hobbs, Greg S <Greg 5 Hobbs@conocophillips.com> Subject: RE: [EXTERNAL]FW: MT6-05 (PTD 218-045) Annular Disposal Application Pressure Calculations Mel — Brian Noel and Randy Kanady can come over to meet with you tomorrow at loam. If I'm available, I'll call in from the rig. Does that work for you? Thanks. Diana Guzman / Nina Anderson Alpine Rig Engineers — Doyon 19 ConocoPhillips Alaska Inc. Drilling & Wells Main Office: 907-670-4351 n2059a'onocophilllos.com From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Sent: Monday, October 29, 2018 8:54 AM To: Anderson, Nina M <Nina.Anderson@conocophillips.com> Subject: RE: [EXTERNAL]FW: MT6-05 (PTD 218-045) Annular Disposal Application Pressure Calculations Nina, Your point is understood. (I see that we have weaker formations below the shoe for the test I sent you.) We can discuss if you like. Can you come over tomorrow at 10:00 am? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission BA ERES 010 PRINT DISTRIBUTION LIST F�UGH a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-05, MT6-05L1, MT6-05PB1, MT6-05PB2 FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Paul-Canizargag hge.com STATUS Final COMPANY RECEIVED SEP 19 2018 Please sign and return one copy of this transpl�itlal+f�C /'N ConocoPhillips Alaska, Inc. �\..114a V �l Ricky Elgarico. ATO 3-380. 700'G' Street. Anchorage, Alaska 99501 to acknowledge receipt of this data. LOG TYPE GR-RES-DEN-NEU LOG DATE June 23, 2018 2 1 8 0 4 5 TODAYS DATE September 18,2018_ 29 6 8 7 Revision Replacement: No Details: Rev. Requested by: --- ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V ConocoPhillips Alaska, Inc. Ricky Elgarico. ATO 3-380. 700'G' Street. Anchorage, Alaska 99501 2 Alpine Wells Supervisor, NSK-33 P.O. Box 196860 lnchorage, Alaska. 99519-6860 3 ASRC, Attn: Teresa Isom 3900'C' Street, Suite 801 Anchorage, Alaska 99503-5963 4 Wayne Svejnoha BLM State Office 222 W. 7th Ave., Suite#13 Anchorage, Alaska 99513-7504 5'AOGCC ATTN: Natural Resources Tech 1333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 MT6-051 is located in a federal oil and gas unit. Only with respect to the [MT6-051 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. FIELD ICD/DVD FINAL FINAL PRELIM LOGS (las, las, dlis, PDF, META, SURVEY REPORT LOGS Final Surveys) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 8 lu 10 01 B 1 0 B Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 1 1 0 BA UGHER PRINT DISTRIBUTION LIST IES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-05, MT6-05L1, MT6-OSPBI, MT6-05PB2 FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT Alaska RECEIVE SEP 19 2018 se sign and return one copy of this transmi �k7 ocoPhillips Alaska, Inc. IcC y Elgarico. ATO 3-380. 'G' Street. forage, Alaska 99501 data. LOG TYPE GR-RES-DEN-NEU LOG DATE June 23, 2018 AUTHORIZED BY Paul Canizares � ,� 8 O 4 EMAIL Paul. Canizares@bhge.com TODAYS DATE September 18, 2018 Revision 29689 STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDI ILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V I ConocoPhillips Alaska, Inc. Ricky ElgariCO. ATO 3.380. 1700'G'Street. Anchorage, Alaska 99501 2 [Alpine Wells Supervisor, NSK-33 P.O. Box 196860 Anchorage, Alaska. 99519-6860 FIELD I FINAL CD/DVD PRELIM I LOGS (las, dlis, PDF, META, FINAL SUR EY REPORT LOGS CGM, Final Surveys) # OF PRINTS # OF COPIES II OF COPIES # OF COPIES jj 4 jj L11 3 ASRC,n: resa AnTeImm 0 0 0 0 0 3900 'C'Street, Suite 801 iAnchorage, Alaska 99503-5963 Wayne Svejnoha I 0 0 0 0 FILM State Office 0 222 W. 7th Ave., Suite#13 Anchorage. Alaska 99513-7504 5'IAOGCC ATTN: Natural Resources Tech 0 0 1 0 0 1333 W. 7th Ave., Suite 100 (Anchorage, Alaska 99501-3539 - '1'6-OSJ is located in a federal oil and gas unit. Only with respect to the [MT6-051 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 1 1 0 BAPRINT DISTRIBUTION LIST 1-IIIIJGER HES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-05, MT6-05L1, MT6-05PB1, MT6-05PB2 FIELD Greater Mosses Tooth Unit COUNTY BHI DISTRICT ALPINE Alaska AUTHORIZED BY Paul Canizares EMAIL Paul. Canizaresnnbhoe.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX HALL NOT DELIVER TO P.O. BOX) PERSON ATTENTION _ _..V ,y Elgarico. ATO 3-380. 'C' Street. horage. Alaska 99501 Nn REECEIVED SFF 19 2018 Please sign and return one copy of this transpli��T{r�h ConocoPhillips Alaska, Inc. 'A. V 4.l Ricky Elgarico. ATO 3-380. 700 'G' Street. Anchorage, Alaska 99501 to acknowledge receipt of this data. LOG TYPE GR-RES-DEN-NEU LOG DATE June 23, 2018 $ 0 4 5 TODAYS DATE September 18, 2018 29 6 90 Revision Details: Rev. Requested by: --- FIELD I FINALCD/DVD FINAL PRELIM LOGS (las, dli"s PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 9 4 0 0 7 2 Alpine Wells Supervisor, NSK-33 0 0 0 0 0 P.O. Box 196860 j (Anchorage, Alaska. 99519-6860 3 'ASRC, Attn: Teresa Imm 3900'C' Street, Suite 801 (Anchorage, Alaska 99503-5963 4Wayne Svejnoha BLM State Office 1222 W. 7th Ave., Suite#13 Anchoraee. Alaska 99513-7504 3CC ATTN: Natural Resources Tech W. 7th Ave., Suite 100 horage, Alaska 99501-3539 0 0 T 0 0 1 0 i 0 1 0 0 1 0 T6-05] is located in a federal oil and gas unit. Only with respect to the [MT6-051 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 1 1 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION jRECEW WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: Oil Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development L ' Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 7/14/2018 14. Permit to Drill Number/ Sundry: 218-045 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 5/12/2018 15. API Number: 50-103-20771-00-00/50-103-20771-70-00/ 50-103-20771.71-00 4a. Location of Well (Governmental Section): Surface: �vi;16' FNL, 3171' FEL, Sec 6, T10N, RX, UM . Top of Pr , uctive Interval: T.1 (` 11414' FNL, 3150' FEL, See 36, T11 N, R2E, UM Total Depth: 921' FNL, 858' FEL, Sec 26, T11 N, R2E, UM 8. Date TD Reached: 6/27/2018 16. Well Name and Number: MT6-05/MT6-05PB1/MT6-05PB2 9. Ref Elevations: KB:88.7 . GL:37.2 • BF: 17. Field / Pool(s): 7 Greater Mooses Tooth UnitOApbh* O 10. Plug Back Depth MD/TVD: . 1112718001 , 18. Property Designation: _ AA081798, AA081818, AA092346 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317060 ' y- 5945544 Zone- 4 - TPI: x- 312167 y- 5949792 Zone- 4 Total Depth: x- 309322 y- 5956638 Zone- 4 11. Total Depth MD/TVD: - 1739117886 - 19. DNR Approval Number: 932, 533, 000, 932, 553,000, 000,000,000, 12. SSSV Depth MD(f VD: NONE 20. Thickness of Permafrost MDITVD: . 1260/1253 5. Directional or Inclination Survey: -Yes ❑+ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: < 11106/7999 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/Neu/Den/CBL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 20 94 H-40 Surface 115 Surface 115 42 Existing, cement to surface 13 318 45.5 L-80 Surface 2014 - Surface 1977 13.5 1044 sx 11.0ppg LiteCrete, 350sx 15 Anna 6A,�q G 95/8 29.7 L-80 Surface 8921 - Surface 7123 9.875 104 sx 12.2ppg Class G 241 sxt . 7 26 L-80 Surface 8654 Surface 6934 8.75 Tieback 7 32 L-80 8641 11174 6925 8006 8.75 78 sx 12.2 ppg Class G 4.5 12.6 L-80 11034 17192 17990 7892 6 Slotted Liner 24. Open to production or injection? Yes 0 • No ❑ If Yes, list each interval open (MDITVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 11073-17192 MD and 7995-7892 TVD COMPLETION D TE VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD)TVD) 41/2 10819 10814/7963 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 5/2017 NTINUED ON PAGE 2 -t - 5 t d Submit ORIGINIAL RgDMS`�`SEP 0 5 209 1, 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� , Sidewall Cores: Yes ❑ No I] ' If Yes, list formations and intervals cored (MD(f VD, From/To), and summarize Ihhology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1260. 1253 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10857 7969 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C C-30 2126 2083 C-10 2533 2450 K-3 3694 3413 Albian 96 4725 4166 HRZ 9003- 7182 Kalubik 9114 7261 LCU 9368 7436 Top Alpine 10857 7969 TO 17391 7886 MT6-05PB1 11936 8051 MT6-05PB2 12406 8012 Formation at total depth: Alpine C ' 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic 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. ner 20 AAC 25.07n 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Weifeng Dai Authorized Title: Alaska Drilling Manager Contact Email: Weifenq.DaKbcqb.corA Contact Phone: 265-1077 Authorized/n� l / Signature: �. U� Date: 6LA INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item tb: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, 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 512017 Submit ORIGINAL Only WNS PROD MT6-05 /'��,s�� well Attribute Max Angle' TD �°o toci;F�hilfip5 Fleln Name WeIIEore FPWWI WeI1Wre 31alus ncl l°I MU IN. Fct Blm lhRB Alaska, Inc. LOOKOUT 5010320]]100 PROD 594 15.93132 1],3910 I ILAST WO. .Teas, emxofel sidep. Last Tag vnYwluL+reus keen AnmLLiM EM DNe oepml ) lest Mo48y LAST TAG: lenllalt NPNOER: A3 If Last Rev Reason on pay last am a, REV REASON: Install GILD 8x92018 6aeM1mbh Casing .,fringe caslne D=a=ripNon On (I) Ip grit iop@Ke set oepin lnNpl se(pepinlrvpl... 9400 ll -_Grace CONDUCTOR 20 19.12 35.5 1150 115.0 94.00 H40 To Welded aE Welded wxOUCTOR:vsuso Caste oescrlpnon noun) In(Inl Tap Win SM Cape, pea) eatuesu l(Npl"' Winen P.-JurWe SURFACE 13318 1242 36.5 2,014.5 1,9T7.1 68.00 L-80 Tap Tllfeatl TXP Casing Descridlan On (in) In(inl Tap BULBI agBgan IMS) Set aeWll (IVB)... WN.an 11... 0, Ma INTERMEDIATE tl1 9N8 8.84 34.6 8,920.8 ).123.1 40.00 L-00 TPoThrwO TXP CatinB Descrigian OO grit IB 6n1 Top MKBI Set Depin (M(al Sal BePm(IVBL.. WtlLen0 grade TIEBACK STRING ) 6.28 32.6 8,6538 6,934.5 26.00 L80 Top TM1rvy] BTCM NIPPIE:1.0127 SURFACE 3as2.mas Casing Dessnplion On (in) In (in) IT.,MKBI Sal Depin MNBI Sal Depin lNol... WnLen (1...6Ma SDL LINER 7 628 186407 111]3] 18,0057 3200 L-80 Top TI,rcM Tenaris Blue Liner Details ws UFT: 3.dB4 NommauD Top MKBI Toplrvol tonal I Top inti r) I lym Use Com MI 86407 6,925.21 45.04 PACKER SVXLlm Hanger Packer 7.37 GASUFTl6490.7 6]33 6, 48.3 4505 SEAL A55Y Latching bulletseals NO-GO (Seals 5]e') 8RPRODlLNER fi1 1 6,50.2 4505 S9dbp Sleeve nnu, Liner Sleeve 1735 6,956.5 45.05 UI H me, Wck Dnnect PuB.11el eas7" M CONNECT Tenaris Blue E6,07 TICBADKSTRWG. s2OEdecu 11,167.4 8,005.1 84.69 STABILIZER Reamer 5MDO2e, w1 Spline r A4]"3 N MY5110 Tenaris Blue ion Indira) ID OnI Topplain Sonsion(M(al Set Deem ITVOL.. WbLan 0... Gra4e TOP Ts"S 41/2 3.96 110340 1],191.8 ],891.6 1260 L-80 TXP ils Toplrvol MKel Tap Incl rl ItemoeaCann O oN,.0 ],990.2 82.1 PACKER HR P w61epl1ed 5. 'upper iQ) 4. 75" lower (10.35) H521 pin 3.8]5 GAS UpT;1.029 11 065.5 7.994.1 82.90 I HANGER 4-1/2 x 7" Flex Lock V TXP B.P 3.940 GAUGE; T3OEU9 Tubing Strings Tuning Description "73 Ma...lp,.nj TUBING 4112 3.96 iop lnKel 29.3 SN Depth ln, 10,8187 eel Depin lNp l... ],963.5 1216, 1 12.60 Gratle L-80 Top Conne=Ilon Hyd563 umPLE; 10,14z9 PRODUCTION Completion Details NOGOLGCATGR; ID.e0.J SEALABay0AE44 :l RAOKEB>I0,9139 Top toxo) mpyal Top MKBI (MLaI 1°) BE' "'SCOM Nanuwl M(in) 293 29.3 000 HANGER FM 4-12'TUISN Hanger Hyddl 563 39 20127 1,975.5 19.28 NIPPLE NIPPLE,IANDING,412',X,3S ", HYD563 3.813 10,084.9 7,7997 88.54 GAU Ec SONSMIR Gauge Mandiel ( wl endapsulavel -wire, 3. 65 4-12" 12,60 HYD563, PxP wlwupling W. 10=2 SEAL BORE, Unde4 NaoKnasr: 109Y.3 10,1419 ],8216 70.73 NIPPLE LH,LAN 11 B, HYD wiN RH ug InsMlled ]2° (10,191)'D84iE Lock rated b 8,000Idea Body JJ50 PR002 LINER 10,934S- 1s,=13 LEE BD�1 vi BE. I0vi 3 3 I' 10,803.3 7,961.5 .88 NO Locator NOGG 5]6"OD LOCATOR 3.50 19604.4 7,%17 8269 SEALASSY eal Assembly Top of Seals 144' up IT Mule shoe 3.950 Tuning oescsi union Suring Ma... Dynl Top1M(Bl SN DePM BLSet Ce pm (TVDI I... WIIIdM Gra4e PROD LEM ASSY 4.6 3.95 10,814.0 11,0496 7,9922 1260 L-80 TOPConnedion Hyd563 NIPPY: 11.Nz.7 Completion Details SEAL ASSY. 11.042 ToToo Incl ----- BI IR rl Its.Ides COT MIR Nominal 109n1 10, 140 7,96. 8273 PACKER HRDE ZXP w/18'sealbore eln. 5.00 ID 3.800 10,92 .2 1 7,9]].6 82.:35 XO Top of LEM 3.700 WRIPSTOCK 1I USE 10,935.4 ),9). 82.85 EAI -BORE Upper Helix w13.868" Seal Son (10,9R.81') 3.680 1 ,938.3 ],97.1 8285 HOOK -ASSY Latch 225' below HBBk Hanger Internal Helix 3.688 10,938.3 7.97 4 82.85 LEM Lateral Erin Module "B' position 1 3.688 SDLLWER, Rew.alyln]3.688 10.951.3 ], 0 8286 SEAL BORE Seal Bore 3.688" 11,002.8 ], 8fi.4 82.89 NIPPLE Landing Nipple 331T'X' profile, HYD521 4720" 3300 11,042.6 ].991.3 82.91 SEALASSY BUIIeISESIASJemblyw/4875"ODSeals 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tep(NDI TOPaIKB) MKBI Top lrwl rl Ides cpm Run Day In (in) 11,106,21 7.99921 82.1 WHIPST00K IVIRIPSTOOK TOW 11,106. I-1111.5 &181201;3 Mandrel Inserts st pnI N TOPRVDI Va.lehB Pw[S- TRO Run Top MKB) MBI Msks MWe1 OD lin) Sery Type Type Ilnl (ps9 Run pine Co. 7,559.4 3,3 5 Camco KB G-2 1 GAS LIFT LV In, I 0.188 1,]36.0 8/9/2018 BK 2 64907 5d 0 Camco KBG-2 i GAS LIFT GLV BK 0188 17]70 8/9/2018 BK 3 10,017.8 2774.1 Camco KBG-2 1 GASLIFT OV BKO-3 0250 81812010 8K0- Notes: General & Safety Ena pay IAnnMNwn NOTE PROD 1 LINER. 11 N48 1],1919 I STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION ECEIVED enc, 14 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil❑+ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑� Exploratory ❑ GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: r{hhi 14. Permit to Drill Number/ Sundry: 218-045 3f $ -2 3. Address: 7. Date Spudded: 15, API Number: ' P.O. Box 100360 Anchorage, AK 99510-0360 50/a/, rT/" 50-103-20771-00-00/50-103-20771-70-00/ 8. Date TO Reached: 50.103-20771-71-00 4a. Location of Well (Governmental Section): 16. Well Name and Number: Surface: 216' FNL, 3171' FEL, Sec 6, T1 ON, R3E, UM 6/2712018 MT6-OS/MT6-05PB1/MT6-05PB2 Top of Productive Interval: 9. Ref Elevations: KB:88.7 17. Field / Pool(s): 1414' FNL, 3150' FEL, Sec 36, T11 N, R2E, UM GL:37.2 BF: Greater Mooses Tooth UniOAlphine Undefined Oil 10. Plug Back Depth MD[TVD: 18. Property Designation: Total Depth: 921' FNL, 858' FEL, Sec 26, T11 N, R2E, UM 11127/8001 AA081798, AA081818, AA092346 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MDlTVD: 19. DNR Approval Number: Surface: x- 317060 y- 5945544 Zone- 4 1739117886 932, 533, 000, 932, 553,000, 000,000,000, TPI: x- 312167 y- 5949792 Zone- 4 12. SSSV Depth MD1rVD: 20. Thickness of Permafrost MDrrVD: Total Depth: x- 309322 y- 5955638 Zone- 4 NONE 1260/1253 5. Directional or Inclination Survey: Yes ❑Z (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) 11106/7999 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/Neu/Den S C tAi10 `(J n 3. CASING, LINER AND CEMENTING RECORD WT. PER GRADE CASING FT SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD D AMOUNT TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 Surace 80 Surface 80 42 Existing, cement to surface 10r78 45.5 L-80 Surace 1794 Surface 1700 13.5 1044 s 11.Oppg LiteCrete, 350sx 7.62f 29.7 L-80 Surace 8325 Surface 4004 9.875 104 sx 12.2ppg Class G Class 4.5 12.6 L-80 11034 17192 7990 7892 6 Slotted Liner y� 0 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MDlrVD) Size and Number; Date Perfd): 41/2 10819 10814/7963 Slotted Liner @: 17192 MD and 7995-789 11073-17192 MD and 7995-7892 TVD COMPLE7ION PATE, /� /� Y 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFI .fo DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: Production for Oil-Bbl:Gas-MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Press. I 24 -Hour Rate Form 10-407 Revised 5/2017 RBDMS_<11`_\ AUG 15 20WNTINUED ON PAGE 2 by ,5o" 4 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1260 1253 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10857 7969 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C C-30 2126 2083 C-10 2533 2450 K-3 3694 3413 Albian 96 4725 4166 HRZ 9003 7182 Kalubik 9114 7261 LCU 9368 7436 Top Alpine C 10857 7969 15953 j M T6-05PB1 11936 8051 6051 'V MT6-05PB2 12406 8012 �� y ` Formation at total depth: Alpine C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination su core analysis, paleontoloaical report, production or well test results, per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. t , '� l Authorized Name: G.L. Alvord Contact Name: Weifeng Dai 41, Authorized Title: Alaska Drilling Manager Contact Email: Weifen .Dai& co .cam Authorized Contact Phone;. g_ 077^ 4 z Z Signature: -�. Date: 14I D 1-6 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Saft Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only MT6-05 Multi -lateral Producer, Pre -Completion Schematic 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface 0❑ 133/8" 68 ppf L-80 TXP to TD Surface Casing @ 2041' MD / 1,980' TVD Ocemented to surface z 4-1/2" 12.6 ppf L-80 Hydril 563 to 10,818.65' MD ,� qo N Tubing / Liner Completion: 1) 4-%" Landing Nipple (3.813" X) @ 2,012.68' MD 2) 4-Y2' x 1" GLM @ 3659.39' MD 3) 4-Y" x 1" GLM @ 6490.64' MD 4) 4-%` x 1" GLM wl SOV @ 10,07.78' MD 5) 4-'/z" SLG DHG @ 10,084.84' MD 6) 4-%" Landing Nipple (3.75" DB) @ 10,147.89' MD 7) Liner Top Packer / Hanger @ 10,813.94'MD w/ Tie Back sleeve 8) LEM and Hook Hanger 9) 4" Landing Nipple (3.313" X profile) @ 11,003' MD 10) Liner Top Packer/ Hanger w/ Tie Back Sleeve GL O 9 5/8" 40 ppf L-80 H563 (to 1,335' MD) 9 518" 40 ppf L-80 BTC (to 3,981') 9 5/8" 40 ppf L-80 TXP (to 6,790') 9 5/8" 40 ppf TN -80 HC TXP (to TD) @ 8,921' MD / 7,125' TVD TOC of 9 5/8 -7,921' MD O O O6 L1 Window- Baker Hook Hanger G� O Junction 10,864' MD/ 7941' TVD (� 4-1/." 12.6# L-80 TXP Liner 6" Hole, TD at With Pert Pups at 15,195' MO \ V Top Alpine C o 0 0 0 0 0 0 0 0 10,828' MD / 7937' TVD 0 0 0 0 0 0 0 0 0 io 4-1/." 12.6# L-80 TXP Liner 6" Hole, TD at 7" 26 ppf L-80 Tenaris Blue/H563 Liner With Pert Pups at 17,391' MD to 11.163' MD / -7,975' TVD @ 83 deg P� y )CA a t4,+ Aba. &S MT6-05 BHA Abandonment 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface 13-3/8" 68 ppf L-80 TXP to TD Surface Casing @ 2,041' MD / 1,980' TVD cemented to surface bf'/ 0e/4�/ Z6�-y�z,` 9 5/8" 40 ppf L-80 H563 (to 1,335') 9 5/8" 40 ppf L-80 BTC (to 3,981' MD) 9 518" 40 ppf L-80 TXP (to 6,790' MD) 9 5/8" 40 ppf TN -80 HC TXP (to TD) @ 8, 921' MD / 7,125' TVD TOC of 9 5/8 — 7,921 ft MD ('� ,%4'vj�6s Abandonment Plan. S� G jj//�? a 1) Bottom of fish #1 @11,870'. 2) Top of fish #1 @11,342'. p 3) Bottom of fish #2 @ 11,298'. 4) Top of s p � clsh #2 and ement @ 11,118 of cement @ 11,234' 5) Top of . /t/ press RA source depth: Density 11,817,78', Neutron 11,807.53'. Top Alpine C O O 10,945' MD / 71979' \N�/ F-- e6i WNS PROD MT6-O5 13 TD /�/�/y��yy�_ E'er CaiocoPh)Ihps Alaska, Inc MWComment Well LOOKOUT SSSV'. Aftribu mu Hoar• MM Name WeII Wre APWW WeII WreS lus M01. PgO (RNe1 50103207]100 PROD 5.94 1593132 1]391.0 N25(on.) OaR Annotation Entl Dah 36Gfp In) Rip Release Dam NIPPLE LAST W0: 36.47 711412018 Tag Ene Dace Oeplx lRn01 12atMM BY TAG: lennan "Tam,dl"IfIs:4142PM Ve0[el¢iemMcle[>lal) Last P-motlien IAST IxwGER-a' ............... .••.. Last REV REV Rev Reason EHE DNa Last Mod By REASON: New well 802018 lennalt Casing Strings Description oD lint ID Om Tov Rne) sn DevlM1 lnnB1 set Deptx tlYol... wuLen p... Gratle Top Thread 20 19.12 36.5 115.0 1150 9400 HAD Welded Descdpnan Runs) ID bol ToplmBl Sel OepIF IRN01 9e10ep1x IND1... wVLen 11... Gratle Top IDrW 1318 1242 36.5 2,014.5 1,9]].1 moo L-80 TXP description oD hnl IDIIN Top MJKER sX1 DePlx lnuBl Bet DeWx ITVT11... 40,00pWLub... L-8Ea TXP #1 9518 884 34.6 8,920.8 7,123.1 40.00 L-80 T%P OD lin) ID PnI Top gtl(BI sNDem,") #et begin 11VD1... wDLan IL.. GrWa Tei Tnna4 STRING 7 6.28 32.6 8,653.8 50,15 26.00 180 BTCM DascriPnon OD (1n1 ID lint Top InKB) SNDepN ImBI Bet Ceptlr IND1- waLerr (1... Gratle TePTxratl SDI LINER 7 628 8,640] 111]37 8,0057 32.00 L-80 Tenaris Blue couOumoR:39sns0 NIPPLE', 302] Caeme CONDUCTOR CSIrrp SURFACE Cuing INTERMEDIATE CulnOOescdpion TIEBACK Culn9 Liner Derails Nominal ID ltd FALE.B30115 GP6 LIFT: 3.859.1 GA6 uFT: 4497.] Loin bol T[p IRKB) ibvlry 6925.2 Topmcl fl Ilam cea ].376 8, O] 6,925.2 4504 PACKER SVX Liner Hell9er Pager 8.7.3 6, DO 45.05 SEAL ASSY Latching bullet seals N 0(Sems 5.78') SAW 8.67 .11 6, .2 4505 Bing Sleeve HRD{Liner Sleeve 7.7 5 8 .0 6,956.5 505 CONNECT ED nst uiC mnetlwlBulln eals7'3 # 615 nEBAOKSTRBIG;32.64.H3e 11,1 74 8. .1 84.69 STABILIZER MYS110 Tened Blueer w/Spline ro Ile, ]' # RID Casing Description OO in ID lint Top IXKB) $et Depm lM`BI BN DeIrN ITVDL.. WtlLen b... Grak, Top TM1Rad PROD t LINER 4112 3.96 11,034.0 17,1918 7,891.6 12.60 L -SO TXP Liner Details Nominal lD IH TER MEONTE X1; ON DI 4�e Top (MB) Tap (TVD111 ;11 Topinclfl Ibm OK Com Iln) 110 0 ),990.2 82.91 PACKER HRD Pwlscepped xL S. "upper t')4. 3875 lower 110.35') H521 pin GA6 UFT; 11.119 11065.5 1.994.1 8290 HANGER 4-12"xT'Flex LockVTXP BxP 3940 Tubing Strings Tubing Deseret n sm D Ma... l0 on) Top lone) bel Depm ln.. set Deem lrvDl l... w1pIJM1 Grade Top Ce3necaon TUBING 4112 396 29.3 10,8187 7.963.5 12.60 L-80 Hy0563 GAVC£' I°'PA.p NIPPLE,10147II NOGG LOCATOR; load 3 REAL Assn L.I4 PACRER;1D.a09 PRODUCTION Completion Details Nem -I rov ITVD) on no Com ID bra) Top(In(0) (aK0) I non MS 293 HANGER FMC 4-19 Tubing Hanger Hydn153 3958 2,012.7 1,9755 1928 NIPPLE NIPPLE,(ANDIN ,4112',%,3.813', HYD 563 3813 XO;10A522 NODKABfiYIlGdm3 PROD RUINER; 10.954.6 0,084.9 7,79] 68.54 GAUGE lumberyer dupe Ma r (S cal encapsulated l -wire, 3.865 0.112" 12.8# HYDM3, PW wlcpuplinA - 10,10.9 7, 6 70.73 NIPPLE IP .3.76' HY wit lug Body 3]50 Installed 07 (10,191')'DBEE Lock rated to 6,000 psi 15.89.1 LEM'. m.9m3 10,803.3 7.91-5 82.68 Lccabr No430VIE 3.950 REAL BORE; 10.m13 LOCATOR 19804.4 7,61] 82.69 EALASSY Seal Assembly Top of Seals344'up fmIn Mule shoe 3.950 sup'. tt.am.] 6EALASsal,W36 wwP6TOLK++.+m2 sOLunER; e.e4a]-++m] Tubing Due ntbn Snme Ma- ID (ln) Top InKB) Bet Depm 16. eel Depm (ND14.. WlbaRp Grade Top Conn. PROD LEM ASSY 4.6 395 19814.0 11,0496 ],992.2 12.60 L$0 Hy0563 Completion Details Nominal Top TOP maCon,ID (in) Top(Itl(0) 0"81 f) IIem OK 10.814.0 7,9629 82.73 PACKER HEDE Z%P w/ 16'sealbore ea. 5.1W ID 3'800 10, .2 7,971.6 82.85 XO Top o LEM 3.700 10,8354 7.9780 8285 SEAL BORE Upper HeiiXw SISEVSeal Bond (10, 3NN# 1019 .3 7,978.1 8285 700K 'ABBY Latch 2.25' belay Hook Hanger Internet Heng 3688 10,938.3 7,978.4 8285 LEM Laterel Enoy ModuIs-ppgres,l .fi88 10, 513 7,980.0 82. SUl-BORE Seal Bore 3.688' 3.688 11 028 7,9854 8289 NIPPLE Lending Nipple 3313 rprolle,HYD521 4.7 3300 11042.6 7,9913 8291 SEALASSY Bullet Seal Assembly IN/ 4875"OD Se61s 3.950 Other In 14019 Wireline retrievable plugs, utilities, pumps, fish. etc.) Top(TND) Tep(nn0) (Mm) llr10S21 7,999.11 Topincl r) 62.92 Dee °win Pop OM ID(m) WHIPSTOCK juiphipaidna TOW 11,1062'18 .11,119.5 fi/182018 Mandrel Inserts st on Top veNe IeLn pensMe TRO Run N Tuii (MB) Make MMN OD(Inl Son, Th", put (in) ding) Run. Co. 1 3,6590 3,384.5 Camco KBG-2 1 AS DFT GLV DV 1.000 ]1121201 2 5.408.0 Camco KBG-2 1114 SLIFT GLV OMK .188 1,TT1.0 01 ,49D.J 3 10,01]8 7]74.1 Camco KBG-2 1114 GAS LIFT OV OMN 0.250 8182010 Notes: Geneml & Safety End Dah Annoblbn NOTE: PRI I LINER: II.OM.O 1].dh P�l ,A -N WNS PROD MT6-05L1 �.W IlJ{ �Jf l Ei"�p$0 �.onocZPh P Alaske. Int LIeW LOOKOUT Well Attribt Maz nngL v 6 6. Name glacre APN11Wl Wefto'PUNS nc l'1 M01.- PCI Bnn IRNBI 501032077160 PROD 6.45 11,16598 15,195.0 ...Pl H2BIppm1 Dale Annotriion Ene Oale KB47 Rg Release 0a@ NST WO'. 364] JI14I2018 Tag Ena oab P. MIKE) I.A. maE er NST TAG: jennall MTSOBtl,alaO14212PM VernalvMMc 1-1 Last AnnemHon Last Rev Reason Hu6OEX:2v.3 AnroMlon ---""""" REV EM OM Lal Moe By REASON: New well 802018 jennalt Casing Strings Casing Strion oD1io1 ID pnl Top (XKaI se cepm lnKal 9---N(NDL.. WXLen IL.. G�aee ropmrae LINER 412 396 10,9348 15,039) ].8845 12 fi0 LA0 TXP ......_..._.................................................... ................. PR002 Liner Details xommal m Top (Me) ToPINOIIXXBI Top Incl l°) INm Des 10,934.8 7,978.0 82.85 HANGER Cam tlo' x 7aB 3 HookHanger 4-112" 12 6# BTC Pin (In) 5.050 WNDUOTOR; RE E-1 Notes: General & Safety End Date I AnnWatNn NOTE: NIPPLE; 2MZ7 SURFACE: 38.E-2,014.5 GPS LIFT; 3859.4 G46 LIFT, 8460.] TIEBPCK STRING; 3280.853.8 INTERMEONTE Yt; ]4.6 B.. OAS LFT, mare .GE; "'.. NIPPLE; 10, 147 9 NOOO LOCATOR: Iaepa3 SEAL A95Y; 1a.4 PACKER; I.E.9 Ko; fo.W2.2 SEAL BORE; 10 M4 HOOKEa"' 10,9A.3 SOL LINER, 9.810]-11.1]3 T PROD 2LINER; IPME- 15=7 r Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Lme Dur(hd Phase Op Code Achvlty Code Time P-T-X OperaW (ftKB) 0.0 End Depth(ftKB) 0.0 5/11/2018 5/11/2018 3.00 MIRU MOVE RURD P trical)lines. R/D lines & eecteam lines. Workservice op rig 00:00 03:00 move check list. Prep rig floor for skidding. 5/11/2018 -2 00 MIRU MOVE MOB P shed, Pits 6 motors 0.0 0.0 complex fomipe ub.Dra lnes&secure 03 00018 0300 05:00 beaver slide. Skid rig floor. Raise stompers & windwalls & prep sub for move. 5/11/2018 5/11/2018 -5.50 MIRU MOVE MOB P & crab over to �MT Move sub off -0 0 0.0 Center sub over well. Lower e sub over 05:00 10:30 stompers 8 wintlwalis &skid floor. stompe. SIMOPS - Spot MPD equipment in cellar. Move pipe shed, pits & motors complex into position. 5/11/2018 5/11/2018 6.00 MIP,U MOVE RD P Hook up steam lines. Work on rig -0 0 0.0 acceptance check list. Connect 1030 16:30 Koomy lines to knife valve. Spot site control & SAFE house shacks. Hook up drain lines & cellar pump. SIMOPS- spot ball ill & work on electric brake. Rig accepted 16:30 Hrs. 5/11/2018 5/12/2018 7.50 WI-RU MOVE RD P Cont. to work on rig acceptance check 0.0 0.0 list. Test gas alarms. Extend diverter 1630 00:00 line. N/U surface riser. Take on spud mud. Prime mud pumps. Install black H2O manifold on conductor. SIMOPS - Spot crane to shim auxiliary brake on draw works. 5/12/2018 5/12/2018 4.00 MIRU MOVE RURD P Cont. to work on rig acceptance check 0.0 0.0 list. Rig up valves & black water line in 0000 04:00 cellar. Secure & barricade diverter line. Mobilize BHA tools & equipment to rig floor. Test gas alarms. SIMOPS - Crane assist to shim auxiliary brake on draw works. 5/12/2018 5/12/2018 2.00 WI-RU MOVE RGRP T Finish repair on electric brake on draw 0.0 0.0 04:00 5/12/2018 06:00 5/12/2018 2.25 MIRU MOVE RURD P works. Install 90' mouse hole. M/U 5" 0.0 elevators. Perform diverter function = 06:00 08:15 A Annular close 27 sec / knife valve �7f1.0 P, open 1.5 sec (AOGCC & BLM waive wittiness). Pre-spud meeting. Rig evacuation drill. Perform Koomy draw down. 5/12/2018 5/12/2016 -3 75 MIRU MOVE BHAH P M/U BHActor s per Baker. Tag bo Som 0.0 115.0 of condu 08:15 5/12/2018 12:00 '9/_1 -2/2018 1.25 MIRU MOVE SEQP P Fillh le w/ 5 bbIs mud.Check 115.0 115.0 leaks. to 3500 1200 13:15 psi (good). CIO air boot on flow line 5/12/2018 5/13/2018 10.75 SURFAC DRILL DDRL P Drill ahead f/115'to 1,137MDI 1,131' 115.0 1,137.0 N .2 Hrs, 725 gpm / 1460 13:15 00:00 psi, Pu wt 94 k, SO wt 94 k, ROT wt 94 k, 60 rpm, 3.5/1.5 k If lbs trq 5/13/2018 5/13/2018 9.00 SURFAC DRILL DDRL P 4g' / 5r986hNDf/ADT 1,137.0 2,024.0 68 HrDs, 850 pm 00:00 09:00 2300 psi, Pu wt 115 k, SO wt 112 k, ROT wt 115 k, 75 rpm, 4.5/1.7 k It lbs trq 5/13/2018 0.75 SURFAC CASING CIRC P Pump 30 bbl nut plug metl sweep 3X 2,024.0 1,871.0 and circ hole clean. Rack back 1 stand 09:45 per B/U f/2,024'to 1,871' E5/13/2O18 5/13/2018025SURFAC CASING OWFF P F/C wl5 rpm (static) 6/D top drive. 1,871.0 1,671.0 10:00 Page 1/47 Report Printed: 7116/2018 Operations Summary (with Timelog Depths) e �y. Wil. ' MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time our(hr) Phase Op Code Anivity code Time P -T -X P Operation l Tttempt to POCH on elevators. (ftKB) 1,871.0 End Depim(ftKB) 1,021,0 5/13/2018 5/13/2018 2.50 SURFAC CASING PMPO success e Pump OOH 10:00 12:30 w/530 gpm f/1,871'to 1,021' 5/13/2018 5/13/2018 0.50 SURFAC CASING CIRC P C i c B/U w1530 gpm / 900 psi. Rack 1,021.0 921.0 1230 13:00 back 1 stand to 921' 5/13/2018 5/13/2018 3.50 SURFAC CASING PMPO P Attcess CH on elevators. Pump 921.0 180.0 (hole OOH 13.00 16:30 w/530 - 300gpm f/921' to 180'. (Dropped Gyro tool @ 700') 5/13/2018 5/13/2018 3.50 SURFAC CASING BHAH P Pump BHA out of hale w/300 gpm 180.0 0.0 f/180' to 86'. Rack back HWDP, Jars, 1630 20:00 & NMFC's. F/86' L/D BHA as per Baker. Bit Grade: 1 -1 -WT -A -E -0 -BU - TD 5/13/2018 5/13/2018 1.50 SURFAC CASING BHAH P Clean &clear floor of BW -tools -&-0 0 0.0 2000 21:30 equipment. 5/13/2018 5/14/2018 2.50 SURFAC CASING KURD P R/U to run casing. R/U Volant & 0.0 0.0 2130 00:00 double stack power tongs, casing bales & elevators. 5/1412018 5/14/2016 0.75 SURF -AC CASING RURD P R/U strap tongs & finish R/U for 0.0 0.0 0000 5/14/2018 00:45 5/14/2018 11.50 SURFAC TB P casing. PJSM on casing. RIH 13-318" 6 L- 2N- ° 0 1,306.0 80 TXP casing to 1306'. M/U shoe 1�- 0045 12:15 track & check floats (good). (Having 5 t G 4 an issue with alignment & galling 3 a FNGPU threads on casing had to swap out ?j several jts casing). 5/14/2018 5/14/2018 1.25 SURFAC CIRC P Circ & cond mud. Stage pumps up to 1,306.0 1,306.0 5 bpm / 90 psi. PU wt 128 k / SO wt 1215 13:30 124 k 5/14/2018 5/14/2018 3.50 SURFAC CASING PUTB P Cont. to RIH 13-3/8" 68# L-80 TXP 1,306.0 1,937.0 13:30 17:00 casing f/1306 to 1937'. 5/14/2018 5/14/2018 1.00 SURFAC CASING HOSO P M/U hanger & landing jt. Land casing 1,937.0 2,014.0 17:00 18:00 on hanger @ 2,014.5' 5/14/2018 5/14/2018 3.00 SURFAC CEMENT CIRC PCirc & cond mud for cementjob 2,014.0 2,014.0 Stage pumps up to 8 psi. 18:00 21:00 Reciprocate pipe. PU wt 175 k / SO wt 155k 5114/2018 5/14/2018 0.75 SURFAC CEMENT RURD 75 R/D casing bales. B/D top drive. R/U 2,014.0 2,014.0 21:00 21:45 cement lines to Volant. 5/14/2018 5/14/2018 1.25 SURFAC CEMENT CIRC P Cont. to circ &cond mud for cement 2,014.0 2,014.0 job thru cement linesw/ 8 bpm / 350 21:45 23:00 psi. Reciprocate pipe. PU wt 180 k / SO wt 174 k. SIMOPS - work on H2S sensor in pits. 5/14/2018 5115/2018 1.00 -SURFAC CEMENT CMNT P PJSM on cementing. Rig load 50 bbls 2,014.0 2,014.0 2300 00:00 nut plug marker in pipe. Dowell pump 1.2 bbls H2O & PT to 2500 psi (good). Dowell pump 100 bbls 10.3 ppg mud push w/4 bpm / 100 psi. Shut down & drop bottom plug. 5/15/2018 5/15/2018 2.75 SURFAC CEMENT CMNT P Dowell pump 357 bbls 11.0 ppg 1.92 2,014.0 2,014.0 ft3/sx yield LiteCRETE lead cement, 00:00 02:45 72.3 15.8 ppg 1.16 ft3/sx yield tail cement 5 bpm. Drop top plug. Dowell pump 20.1 bbls H2O. Rig displace w/268.7 bbls / 2692 stks 10.0 r ppg DrillPlex w/8 bpm / 650 psi. At 250 bbls slow pumps to 3 bpm / 420 psi. Bump plug, pressure 500 psi over to 920 psi for 5 min. Check floats / F/C good. CIP @ 2:38 Hrs. Page 2147 ReportPrinted: 7/16/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur(hn Phase Op Code Activity Coda Time P -T -X Operation (ftKB) End Depth(ftKB) 5/15/2018 5/15/2018 0.75 SURFAC CEMENT WWWH P Disconnect lines to knife valve. Flush 0.0 0.0 02:45 03:30 riser, function diverter annular and flush again 3X w/black H2O. 5/15/2018 5/15/2018 1.50 SURFAC CEMENT TURD P R/D cement lines. B/D same. HID 0.0 0.0 03:30 05:00 volant & UD same. BIC, landing jt & UD same. UD 90' mouse hole. 5/15/2018 5/15/2018 7.00 SURFAC CEMENT NUND P Remove hole fill & bleeder lines. Drain 0.0 0.0 05:00 12:00 lines. Disconnect Koomy lines. N/D riser. N/D diverter annular & knife valve. N/D diverter line. Remove barricade. 5/15/2018 5/15/2018 1.75 SURFAC WHDBOP NUND P N/U well head & test void 1/1000 psi 0.0 0.0 1200 13:45 V10 min good. SIMOPS cont, to remove diverter line sections from back of pad. 5/15/2018 5/15/2018 6.00 SURFAC WHDBOP RE _N P NIU BOPE. Tighten speed head. N/U 0.0 0.0 13:45 19:45 choke & kill lines under rig floor. Tighten BOPE rams doors. SIMOPS - Test gas alarms. M/U rocket launcher 5/15/2018 5/16/2018 4.25 SURFAC WHDBOP MPDA P M/U MPD equipment. N/U MPD 0.0 0.0 19:45 00:00 clamp, orbit valve, flow box, trip nipple, Katch Kan, & 1502 lines. SIMOPS - grease choke, clean pits, install 90' mouse hole. P/U test jt & M/U test plug. 5/16/2018 5/16/2018 3.00 SURFAC WHDBOP MPDA P Cont. to N/U MPD valves. Install test 0.0 0.0 0000 03:00 plug. Fill stack w/H20. Energize accumulator unit. Test MPD system to 250 psi for 5 min & 1200 psi for 10 min on chart (good). 5/16/2018 5/16/2018 1.50 SURFAC WHDBOP MPDA P Remove MPD test plug & install trip 0.0 0.0 03:00 04:30 nipple.Align trip nipple for air boots. 5/16/2018 5/16/2018 0.50 SURFAC WHDBOP KURD P Install 5" test joint. R/U BOPE test 0.0 0.0 04:30 05:00 equipment. Fill trip nipple & lines w/H2O 5116/2018 5/16/2018 7.00 SURFAC WHDBOP BOPS P Test BOPS 25013500 for 5/10 min's 0.0 0.0 05:00 12:00 w/5 lest joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" e P VBR's & blind rams, 5" Dart/FOSV, 10 Q HCR / Man choke/kill, Accumulator �J test, Initial 3020 psi, final 1500 psi, 1 st �Ge2 200 psi recharge = 25 sec's, full recharge = 142 second. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes V1100 psi. AOGCC Brian Bixby witness, BLM Mutasim Elganzoory waived witness via email. (Auto IBOP Fail/Pass) 5/16/2018 5/16/2018 0.75 SURFAC WHDBOP RURD P RID testing equipment & B/D same. 0.0 0.0 1200 12:45 Install 12.375" ID wear ring. 5/16/2018 5/16/2018 4.75 SURFAC WHDBOP BOPE T Bring IBOP tools to rig floor. CIO 0.0 0.0 1245 17:30 upper/lower IBOP assembly. Test same 250 psi for 5 min & 3500 psi for 10 min (good). M/U fedder bolts & wire tie bolts. SIMOPS - install rubber seal underneath flow box. 5/16/2018 5/16/2018 1.25 SURFAC CEMENT BHAH P Bring BHA tools & equipment to rig 0.0 0.0 1730 18:45 Floor. SIMOPS - M/U Baker BPA 5/16/2018 5/16/2018 3.75 SURFAC CEMENT BHAH P M/U 12-1/4" BHA#2 as per Baker rep 0.0 622.0 1845 22:30 to 60'. Plug in and down -load MWD. Cont. to M/U BHA to 622' 5/16/2018 5/16/12018 0.50 SURFAC CEMENT TRIP P RIH w/BHA#2 f/622'to 1750' 622.0 1,750.0 22:30 23:00 Page 3147 Report Printed: 711612018 Operations Summary (with Timeiog Depths) Aim MT6-05 Me Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StaRTime End Time Dur(hr) Phase Op Code ActivM1y Cosa Time P-T-X Operation (ftKB) End Depth (WS) 5/16/2018 5/16/2018 0.50 SURFAC CEMENT DHEO P Shallow hole test MWD tools w/gpm/ 1,750.0 1,750.0 23:00 23:30 psi. Circ B/U & cond for casing test. SIMOPS - R1U testing equipment. 5/16/2018 5/172018 0.50 SURFAC CEMENT PRTS P Pressure test casing to 2500 psi & 1,750.0 1,750.0 23:30 00:00 chart for 30 min (good). 5/17/2018 5/172018 0.50 SURFAC CEMENT PRTS P Finish csg test. & R/D testing 1,750.0 1,750.0 00:00 00:30 equipment. 5/17/2018 5/172018 4.25 SURFAC CEMENT DRLG P Wash down & tag TOC @ 1,925'. Drill 1,750.0 2,024.0 00:30 04:45 out shoe track & rat hole from 1,925' to 2,024'w/750 gpm / 1850 psi, 80 rpm / 1.2 k trq. (Float collar & shoe on depth. 5/17/2018 5/17/2018 0.75 SURFAC CEMENT DDRL P Drill 20'new formation f/2,024'to 2,024.0 2,044.0 04:45 05:30 2,044', ADT .2 Hrs wf750 gpm 11440 psi, 150 rpm / 6.5/2 k trq. SIMOPS - Displace to new 9.4 ppg LSND on the fly 5/17/2018 05:30 5/172018 06:15 0.75 SURFAC CEMENT CIRC P Circ B/U & Gond mud for FIT, pump out of hole (/2,044' to 1,939'w[750 2,024.0 1,939.0 gpm 11250 psi. (No rotation while pulling BHA across shoe) 5/17/2018 5/17/2018 0.25 SURFAC CEMENT RURD P B/D top drive & R/U testing equipment 1,939.0 1,939.0 06:15 06:30 1 1 1 for FIT 5/17/2018 5/17/2018 0.50 SURFAC CEMENT FIT P F t0 18.0 DDD w19 4 ooD mud 1,939.0 1,939.0 06:30 07:00 1.5 bbls @ 890 psi 5/17/2018 5/172018 0.50 INTRMI DRILL REAM P W&R f/1,939'to 2,044'w/750 gp1,939.0 2,044.0 07:00 07:30 1320 psi, 50 rpm / 3 k trq 5/17/2018 5/17/2018 4.50 INTRMI DRILL DDRL P Drill ahead f2,044'to 2,598'MD2,044.0 7k, 2,598.0 07:30 12:00 2,507' TVD, ADT 3.3 Hrs, ECD ppg, 750 gpm, 1440 psi, PU wt SO wt 125 k, ROT wt 132 k, 150 6.5/2ktrq 5/1712018 5/17/2018 11.75 INTRMI DRILL DDRL P Drill ahead (/2,598" to 4,388' MD / 2,598.0 4,388.0 12:00 23:45 3,930' TVD, ADT 8.7 Hrs, ECD 10.3 ppg, 900 gpm, 2560 psi, PU wt 163 k, SO wt 140 k, ROT wt 158 k, 175 rpm, 9.5/4 ktrq. 5/17/2018 5/18/2018 0.25 INTRMI DRILL PMPO P Pump OOH w/425 gpm / 680 psi 4,388.0 4,328.0 23:45 00:00 f14,388'to 4,328'. Paced Ghost Reamer @ 4328.5' between Its #1 & #2 on stand #40 5/18/2018 5/16/2018 0.25 INTRMI DRILL WASH P Wash back in hole f/4,328' to 4,388' 4,328.0 4,388.0 00:00 00:15 1 1 w/385 gpm / 590 psi 5118/2018 5/18/2018 6.50 INTRMI DRILL DDRL P Drill ahead f/4,388' to 5,523' MY/ 4,388.0 5,523.0 00:15 08:45 4,725' TVD, ADT 6.0 Hrs, ECD 10.57 ppg, 900 gpm, 2660 psi, PU wl 175 k, SO wt 145 k, ROT wt 162 k, 180 rpm, 11.5/5ittrq. 5/18/2018 5/18/2018 2.25 INTRMI DRILL RGRP T C/O pulsation dampener on mud 5,523.0 5,523.0 08:45 11:00 pump #2. Reciprocate pipe w/330 gpm / 530 psi, 80 rpm / 6.5 k trq 5/18/2018 5/1812018 0.50 INTRMI DRILL SVRG P Sevice rig & draw works 5,523.0 5,523.0 11:00 11:30 5/18/2018 5/18/2018 0.50 INTRMI DRILL DDRL P Drill ahead f/5,523'to 5,551' MD / 5,523.0 5,551.0 11:30 12:00 4,745' TVD, ADT 0.2 Hrs, ECD 10.57 ppg, 900 gpm, 2660 psi, PU wt 175 k, SO wt 145 k, ROT wt 162 k, 180 rpm, 11.5/5 ktrq. 5/18/2018 5/19/2018 12.00 INTRMI DRILL DDRL P Drill ahead f15,551'to 6,935' MD / 5,551.0 6,935.0 12:00 00:00 5,721' TVD, ADT 8.9 His, ECD 10.6 ppg, 900 gpm, 2750 psi, PU wt 202 k, SO wt 154 k, ROT wl 172 k, 170 rpm, 14.515.5 k trq. Page 4147 ReportPrinted: 7/16/2018 Uperations Summary (with Timelog Depths) 6 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start DepM Stan Time EM Time our (hr) Phase Op C Activity Code Time P -T -X Operation (flKB) I End Deptlt (W13) 5/19/2018 5/19/2018 5.50 INTRMI DRILL DDRL P Drill ahead f16,935'to 7,595' MD / 6,935.0 7,595.0 00:00 05:30 6,187' TVD, ADT 4.1 Hrs, ECD 10.75 ppg, 900 gpm, 2980 psi, PU wt 215 k, SO wt 158 k, ROT wt 182 k, 150 rpm, 16/7 k 5/19/2018 5/19/2018 0.75 INTRMI DRILL CIRC P Circ & cond w/900 gpm / 2980 psi, 7,595.0 7,595.0 05:30 06:15 120 rpm / 8 k trq 5/19/2018 5/19/2018 0.25 INTRMI DRILL OWFF P F/C (static) 7,595.0 7,595.0 06:15 06:30 5/1912018 5/19/2018 1.00 INTRMI DRILL MPDA P Pull trip nipple & install RCD bearing. 7,595.0 7,595.0 06:30 07:30 Break in bearing as per MPD hand w/900 gpm / 2990 psi, 50 - 150 rpm / 7 8 k trq. 5/19/2018 5/19/2018 4.50 INTRMI DRILL DDRL P Drill ahead W7,595'to 8,042' MD / 7,595.0 8,042.0 07:30 12:00 6,504' TVD, ADT 3.3 Hrs, ECD 10.88 ppg, 900 gpm, 3150 psi, PU wt 230 k, SO wt 165 k, ROT wt 190 k, 150 rpm, 17/9 klrq. 5/19/2018 5/19/2018 8.00 INTRMI DRILL DDRL P Drill ahead f/8,042'to 8,933' MD / 8,042.0 8,933.0 12:00 20:00 7,132'TVD,ADTXHrs,ECD11.0 ppg, 900 gpm, 3500 psi, PU wt 230 k, SO wt 165 k, ROT wt 190 k, 150 rpm, 17/9 ktrq. 5/19/2018 5/1912018 3.75 INTRMI CASING CIRC P Pump 30 bbls high wt nut plug sweep 8,933.0 8,819.0 20:00 23:45 & circ hole clean for 3 B/U w/900 gpm /3500 psi, 170 rpm / 9 - 10 k trq. 10.5 ppg In/Out. UD single jt & racked back 1 stand to 8,819' 5/19/2018 5/2012018 0.25 INTRMI CASING OWFF P F/C to determine if 10.5 ppg is final 8,819.0 8,819.0 23:45 00:00 1 mud wt (static) 5/20/2018 5120/2018 2.75 INTRMI CASING CIRC P Cont to circ hole clean for 6+ B/U total 8,819.0 8,629.0 00:00 02:45 w/900 gpm / 3500 -3320 psi, 170 - 150 rpm / 10 k trq. Pumped nut plug sweep after 5th B/U. Racked back 2 stands to 8,629' 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static). SIMOPS - line up MPD 8,629.0 8,629.0 02:45 03:00 equipment to strip OOH 5/2012018 5/20/2018 3.25 INTRMI CASING SMPD P Strip OOH as per MPD schedule 8,629.0 4,863.0 03:00 06:15 V8,629'to 4,863'. Few tight spots, worked thru once and clear. 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static). SIMOPS - PJSM on 4,863.0 4,863.0 06:15 06:30 removing RCD bearing 5/20/2018 5/20/2018 0.50 INTRMI CASING MPDA P Pull RCD bearing & install trip nipple. 4,863.0 4,863.0 06:30 07:00 5120/2018 5/20/2018 0.50 INTRMI CASING CIRC P Circ B/U w/900 gpm / 2760 psi, 180 4,863.0 4,771.0 07:00 07:30 rpm / 7 k trq. Rack back 1 stand f/4,863' to 4,771' 5/20/2018 5/20/2018 3.00 INTRMI CASING TRIP P POOH f/4,771'to 1,939'. Few light 4,771.0 1,939.0 07:30 10:30 spots, worked thru once and clear. 5/20/2018 5/20/2018 0.50 INTRMI CASING CIRC P Pump 30 bill sweep & circ clean 1,939.0 1,845.0 10:30 11:00 w/900 gpm /2100 psi, 120 rpm / 3 k trq. Rack back 1 stand (/1,939' to 1,845' 5/20/2018 5/2012018 0.50 INTRMI CASING OWFF P F/C (static) 1,845.0 1,845.0 11:00 11:30 5120/2018 5/20/2018 0.75 INTRMI CASING TRIP P POOH f/1,845'to 622' 1,845.0 622.0 11:30 12:15 5/20/2018 5/20/2018 0.25 INTRMI CASING OWFF P F/C (static) 622.0 622.0 12:15 1230 5/20/2018 5/20/2018 2.25 INTRM1 CASING BHAH P Rack back HWDP &jars & UD BHA 522.0 0.0 12:30 1445 as per Baker reps f/622' to surface. Bit Grade: 2 -1 -CT -G -X -I -LT -TD Page 5147 ReportPrinted: 7/1612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log smn oepm start Time I End Time our (hr) Phase Op Code Achwy Code Time P -T -X Operation (BKB) End Depth(kKB) 5/20/2018 5/20/2018 1.00 INTRMI CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 14:45 15:45 equipment. 5/20/2018 5/20/2018 0.75 INTRMI CASING W W WH P M1U stack washer to single It & flush 0.0 0.0 15:45 16:30 stack. Functioned rams & flush again. 5/20/2018 5/20/2018 2.00 INTRMI CASING BOPE P Pull wear ring & set test plug. C/O 0.0 0.0 16:30 18:30 upper rams to 9-5/8" solid body. R/U testing equipment. SIMOPS - R/U Volant 5/2012018 5/20/2018F1.50 INTRMI CASING BOPE P Test w/9-5/8" test jt. Annular 250 psi 0.0 0.0 18:30 20:00 for 5 min, 2500 psi for 10 min. Upper rams 250 psi for 5 min, 3500 psi for 10 min. 5/20/2018 5/20/2018 INTRMI CASING BOPE P RID testing equipment. Pull test plug & 0.0 0.0 20:00 20:30 set thin wall casing 13-3/16" casing wear bushing. 5/20/2018 5/20/2018 INTRMI CASING RURD P R/U casing tools & equipment. Install 0.0 20:30 22:00 mud saver on Volant 5/20/2018 5/21/2018 2.00 INTRMI CASING PUTB P PJSM on running casing. M/U shoe 0.0 jV.0 22:00 00:00 track & check floats (good). RIH w/9- IA� 5/8" TN -80 40# TXP-HS casing to 485' 5/21/2018 5/21/2018 6.00 INTRMI CASING PUTB P RIH w/9-578" f/485'to 4.017'. PU wt 485.0 4,017.0 00:00 06:00 1180 k I SO wt 155 k 5/21/2018 5/21/2018 0.50 INTRMI CASING RURD P C/O cup on Volant tool 4,017.0 4,017.0 06:00 06:30 5/21/2018 5/2172018 1.50 INTRMI CASING CIRC P Circ & cond un -even mud wts w/6 4,017.0 4,017.0 06:30 08:00 bpm 1200 psi. Max mud wt observed 11.0 ppg 5/21/2018 5/21/2018 2.25 INTRMI CASING PUTB P RIH w/9-5/8" f/4.017'to 5 476'. PU wt 4,017.0 5,476.0 175 k I SOw[ 45 k 08:00 10:15 5/21/2018 5/21/2018 1.00 INTRMI CASING CIRC P Circ & cond un -even mud wts w/8 5,476.0 5,476.0 10:15 11:15 bpm / 320 psi. Max mud wt observed 11.2 ppg 5/21/2018 5/21/2018 2.00 INTRMI CASING PUTB P RIH w/9-5/8" f/5,476' to 6,361'. PU wt 5,476.0 6,361.0 11:15 13:15 1240 k / SO wt 195 k 5/21/2018 5/21/2018 1.00 INTRMI CASING CIRC P Break circ w/5 bpm 1480 psi 6,361.0 6,361.0 13:15 14:15 5/2112018 5/21/2018 2.75 INTRMI CASING PUTB P RIH w/9-5/8" f/6,361'to 7,669'. PU wt 6,361.0 7,669.0 14:15 17:00 310 k / SO wt 195 It. (Cross threaded 2 its of casing. C/O bad jts.) 5/21/2018 5/2112018 3.00 INTRMI CASING CIRC P Circ &cond un -even mud wts w/8 7,669.0 7,669.0 17:00 20:00 bpm / 520 psi. Max mud wt observed 12+ ppg. Added water & ran centrifuge to condition to 10.5 ppg In 110.7 ppg Out 5121/2018 2.50 INTRMI CASING PUTS P RIH w/9-5/8" f/7,669'to 8,883". PU wt 7,669.0 8,883.0 22:30 370 k / SO wt 220 k 5/21/2018 0.50 INTRMI CASING HOSO P WU hanger & landing it. Wash down 8,883.0 8,920.0 23:00 w/1 bpm & land casing on hanger @ r23:00 8,920.86' 5/22/2018 1.00 INTRMI CEMENT CIRC P Circ& cond mud for cement job. 8,920.0 8,920.0 00:00 Stage pumps to 5.5 bpm 1530 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. Max mud wt out observed 11.1 ppg 5/22/2018 5/22/2018 3.50 INTRMI CEMENT CIRC P Circ & cond mud for cement job. 8,920.0 8,920.0 00:00 03:30 Stage pumps F/5.5 to 8 bpm / ICP 530 psi / FCP 400 psi. Reciprocate pipe 7' due to hanger making contact with lower pipe rams. 5/22/2018 5/22/2018 0.50 INTRMI CEMENT RURD P R/D mud saver. B/D top drive. R/U 8,920.0 8,920.0 03:30 04:00 1 cement lines. Page 6147 Repon Printed: 7/16/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Stan Time End Time our (no Phase Op co AcbWy Code Time P -T -X Operation (ftKB) End Depth (aKS) 5/22/2018 5/22/2018 0.50 INTRMI CEMENT CIRC P Break circ thru cementing lines w/8 8,920.0 8,920.0 04:00 04:30 bpm / 590 psi. PJSM on cementing. 5/22/2018 5/22/2018 3.00 INTRMI CEMENT CMNT P Dowell pump 1.5 bbls H2O & PT lines 8,920.0 8,920.0 04:30 07:30 to 4000 psi (good). Dowell pump 60 bible 12.0 ppg mud push, drop bottom plug, 42.7 WE 12.2 ppg 2.31 ft3/sx yield G class lead cement, 49.8 bbls 15.8 ppg 1.16 ft3/sx yield G class tail S N cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace w/653 bbls / 6543 stks 10.5 ppg 1 -SND w/8 bpm 1820 psi. At 640 bbls slow pumps to 3 bpm / 530 psi. Did not bump plug, Check floats & slight weeping. CIP @ 7:21 Hrs. 5/22/2018 5/22/2018 0.50 INTRMI CEMENT OWFF P Install gauge on Volant & stab into 0.0 0.0 07:30 08:00 landing jt. F/C for 30 min. Floats holding. Well static. SIMOPS - RID cementing lines 5/22/2018 5/22/2018 1.75 INTRMI CEMENT RURD P R/D Volant & back out landing it. UD 0.0 0.0 08:00 09:45 90' mouse hole. Open IBOP's on top drive & B/D. SIMOPS - Prep to N/D BOPE. N/D MPD equipment. RID Katch Kan & hole fill lines. 5/22/2018 5/22/2018 1.25 INTRMI CEMENT W WSP P FMC pull wear ring. Install pack off & 0.0 0.0 09:45 11:00 1 1 test 5000 psi (good). 5/22/2018 5/22/2018 2.75 INTRMI CEMENT NUND P Pull trip nipple & R/D flow line. Loosen 0.0 0.0 11:00 13:45 studs on well head. UD flow box. P/U & move BOPE away from well head. 5/22/2018 5/22/2018 1.50 INTRMI CEMENT NUND P FMC N/U 7" casing spool. Set BOPE 0.0 0.0 13:45 15:15 back on well head. Torque lower flange & test void to 5000 psi / 15 min (good). Torque upper spool to BOPE. 5/22/2018 5/22/2018 1.00 INTRMI CEMENT NUND P C/O upper rams to 4-1/2" X 7" VBR's 0.0 0.0 15:15 16:15 5/22/2018 5/22/2018 2.50 INTRMI CEMENT MPDA P Install flow box. NIU MPD equipment. 0.0 0.0 16:15 18:45 1 1 Install trip nipple. 5/22/2018 5/22/2018 4.50 INTRMI WHDBOP RURD P Install mouse hole. R/U to test BOPE. 0.0 0.0 18:45 23:15 Fill slack w/1-120 & flood lines. Check for leaks. H2O leaking out of MPD trip nipple clamp. Truoble shoot. Decision made to BOPE test without trip nipple. Perform BOPE shell test (good). R/U ball mill to AD LOT. Attempt to PT ball mill lines and having trouble with pumnps. Trouble shoot pumnps. PTY to 2500 psi good. 6/22/2018 5/23/2018 0.75 INTRM1 WHDBOP BOPE P Begin BOPE test w/5" test it. Tested 0.0 0.0 23:15 0000 gas alarms. SIMOPS -AD LOT on 13- 3/8" X 9-5/8" annulus. 5/23/2018 5/23/2018 5.50 INTRMI WHDBOP BOPE P Test BOPE 250/3500 for 5/10 min's 0.0 0.0 00:00 05:30 w/4",5"&7" test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, lower 3-1/2" X 6" VBR's & blind rams, 5" Darl/FOSV, HCR / Man chokelkill, Accumulator test, Initial 3050 psi, final 1400 psi, 1st 200 psi recharge = 32 sec's, full recharge = 172 second. Gas alarms, PVT alarms and flow indicated tested. Draw down on chokes U1100 psi. AOGCC Jeff Jones & BLM Mutasim Elganzoory waived witness via email. Page 7147 Report Printed: 7/16/2018 Operations Summary (with Timelog Depths) Ar--�-N!46 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log stag Depth StartTime End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation htKB) 0.0 End Depth(ftKB) 0.0 5/23/2018 5/23/2018 0.50 INTRMI WHDBOP BOPE P RID testing equipment & B/D lines 05:30 5/23/2018 06:00 5/23/2018 1.00 INTRMI CEMENT MPDA P Install MPD test plug &test 250/1200 0.0 0.0 psi for 5 min. Pull MPD test plug & 06:00 07:00 install trip nipple. 5123/2018 5/23/2018 0.50 INTRMI CEMENT RURD P FMC set 8.75" ID wear ring. SIMOPS 0.0 0.0 07:00 5/23/2018 07:30 5/23/2018 0.50 IN TRMI CEMENT RURD f FMC set 8.75" ID wear ring. SIMOPS - 0.0 0.0 Bring BHAtools & equipment to rig 07:30 08:00 floor. 5/23/2018 5/23/2018 1.00 INTRMI CEMENT BHAH P M/U clean out BHA #3 as per Baker to 0.0 399.0 08:00 5/23/2018 09:00 5/23/2018 4.25 INTRMI CEMENT TRIP P 399' RIH f/399'to 8,746' 399.0 8,746.0 09:00 5123/2018 13:15 5/23/2018 1.50 INTRMI CEMENT PRTS P B/D top drive. R/U testing equipment. 8,746.0 8,746.0 Pressure test casing to 3000 psi & 13:15 14:45 chart for 30 min (good). R/D testing equipment. 5/23/2018 5/23/2018 1.00 INTRMI CEMENT SLPC P Slip & cut 68' drill line. 8,746.0 8,746.0 14:45 5/23/2018 15:45 5123/2018 0.50 INTRMI CEMENT SVRG P Service rig, top drive &draw works. 8,746.0 8,746.0 Calibrate block height. 15:45 5/23/2018 16:15 5/23/2018 0.50 INTRMI CEMENT -(5-0-CF P Wash down f/8,746' to 8,829' w/525 8,746.0 8,829.0 16:15 16:45 gpm 11960 psi. 5/23/2018 5/23/2018 1.00 INTRMI CEMENT -ITR-LG P Drill shoe track &rat hole f/8,829'to 8,829.0 8,933.0 8,933'w/550 gpm / 2000 psi, 65 - 70 16:45 17:45 rpm / 12 k trq 5/23/2018 5/23/2018 0.75 INTRMI CEMENT DDRL P Drill 20' new hole f/8,933' to 8,953' 8,933.0 8,953.0 MD / 7,146' TVD, ADT .7 Hrs 1745 5/23/2018 18:30 5/23/2018 0.75 INTRMI CEMENT CIRC P Circ & cond for FIT w/550 gpm / 1900 8,953.0 8,903.0 psi, 70 rpm / 12 k trq. Rack back 1 1830 19:15 stand f/8,953'to 8,903' 5/23/2018 5/23/2018 0.25 INTRMI CEMENT OWFF P FIC (static) 8,903.0 8,903.0 1915 5/23/2018 19:30 5/23/2018 1.00 INTRMI CEMENT FIT P FIT to 14 0 PP9 (13120 8,903.0 8,903.0 psQw/euipment 10 45 ppg MW). R/D 1930 20:30 testing equipment 5/23/2018 5/23/2018 0.25 INTRM2 DRILL REAM P W&R f/8,903'to 8,953' w/350 gpm I 8,903.0 8,953.0 1000 psi, 70 rpm / 13 k trq. Pump 30 2030 20:45 bbls spacer & displace to 10.8 ppg -SND on the fly. 5/23/2018 5/23/2018 2.25 TNT RM2 DRILL DDRL P Drill ahead SDL rat hole f/8,953' to 8,953.0 9,000.0 9,000' MD / 7,179' TVD. ADT 1.2 Hrs, 20:45 23:00 550 gpm, 1900 psi, PU wt 220 k, SO wt 170 k, ROT wt 190 k, 70 rpm, 12/9.5 k trq. 5/23/2018 5/23/2018 0.75 INTRM2 CSGDRL BKRM P BROOH f/9,000' to 8,872'w/550 gpm I 9,000.0 8,872.0 1900 psi, 70 rpm / 9 k trq. SPR's 23:00 5/23/2018 23:45 5124/2018 0.25 INTRM2 CSGDRL CIRC P F/C (static) Pump 30 bbl 12.5 ppg dry 8,872.0 8,872.0 23:45 5/24/2018 00:00 5/24/2018 5.75 INTRM2 CSGD-RL TRIP P job. POOH (/8,872' to 399' 8,872.0 399.0 00:00 5/24/2018 05:45 5/24/2018 0.25 INTRM2 CSGDRL OWFF P F/C (static) 399.0 399.0 0545 5/24/2018 06:00 5/24/2018 0.75 INTRM2 CSGDRL BHAH P UD BHA#3 as per Baker f/399'to 399.0 0.0 06:00 5/24/2018 06:45 5/24/2018 1.50 INTRM2 CSGDRL BHAH P surface. Clean & clear Floor of BHAtools & 0.0 0.0 equipment. Mobilize SOL components 06:45 08:15 to rig floor. Page 8147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sutra DepM Start Time End rune Our (hr) Phase Op Code Activity Code Tim P-T-X Operation (ftKB) End Depth (RKB) 5/24/2018 5/24/2018 3.00 INTRM2 CSGDRL SHAH P PJSM. M/U 6" SDL BHA as per Baker 0.0 0.0 08:15 11:15 reps. Plug into MWD. M/U bit. Rack back BHA in derrick. SIMOPS - Cont. to bring SDL & 7" liner running components to dg floor. 5/24/2018 5/24/2018 1.75 INTRM2 CSGDRL RURD P R/U to run 7" SDL liner. (power tongs, 0.0 0.0 11:15 13:00 slips, elevators, etcO. SIMOPS - Mobilize inner string working platform to rig floor. 5/2412018 5/24/2018 6.25 INTRM2 CSGDRL PUTB P PJSM. M/U Baker reamer shoe easy. 0.0 2,485.0 13:00 19:15 RIH w77" 26# L-80 Tenaris Blue SDL liner to 2,485'. PU wt 112 k / SO wl 1110 k 5/24/2018 5/24/2018 1.25 INTRM2 CSGDRL RURD P M/U lower quick connect. Clean & 0.0 0.0 19:15 20:30 clear floor. Set up inner string working platform., C-plate, & false table. 5/24/2018 5/24/2018 1.50 INTRM2 CSGDRL BHAH P M/U 6" inner string BHA &RIH to 0.0 159.0 20:30 22:00 159'. (MWD plug into tools & double check connections & communication.) 5/24/2018 5/24/2018 1.00 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrick 159.0 650.0 22:00 23:00 f/159' to 650' (Drift each stand w/2.0" OD drift) 5/24/2018 5/24/2018 0.25 INTRM2 CSGDRL SFTY P Perform kick while tripping drill with 650.0 650.0 23:00 23:15 kick stand & SDL. 6.5 min response time. Hold AAR on drill. UD kick stand. 512412018 5/25/2018 0.75 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrivk 650.0 1,565.0 23:15 00:00 f/650' to 1,565'. (Drift each stand w/2.0" OD drift) 5/25/2018 5/25/2018 1.00 INTRM2 CSGDRL TRIP P RIH inner string w/4" DP out of derrivk 1,565.0 2,531.0 00:00 01:00 f/1,565' to 2,531'. (Drift each stand w/2.0" OD drift) 5/25/2018 5/25/2018 0.75 INTRM2 CSGDRL HOSO P No Go out, M/U space out pups & 2,531.0 2,560.0 01:00 01:45 space out inner string. M/U HRDE running tool & tie in innerstring to liner. 5/25/2018 5/25/2018 0.50 INTRM2 CSGDRL RURD P RID false table, false bowl & slips. 2,560.0 2,560.0 01:45 02:15 Clean & clear floor. SIMOPS - Baker reps install blocks & locks on quick connect. 5/25/2018 5/25/2018 0.75 INTRM2 CSGDRL BHAH P M/U flow diverter, stabilizer, & float 2,560.0 2,59-20- 02:15 03:00 sub. 5/25/2018 5/25/2018 0.50 INTRM2 CSGDRL TRIP P RIH w/SDL f/2,582'to 3,050' 2,582.0 3,050.0 03:00 03:30 5/25/2018 5125/2018 0.25 INTRM2 CSGDRL DHEQ P Shallow hole test MWD 3,050.0 3,050.0 03:30 03:45 5/25/2018 5/25/2018 6.00 INTRM2 CSGDRL TRIP P RIH w/SDL f/3,050'to 8,730' 3,050.0 8,730.0 03:45 09:45 5/25/2018 5/25/2018 0.25 INTRM2 CSGDRL MPDA P Pull trip nipple & install RCD bearing. 8,730.0 8,730.0 09:45 10:00 5/2512018 5/25/2018 0.50 INTRM2 CSGDRL TRIP P RIH w/SDL f/8,730'to 8,995' 8,730.0 8,995.0 10:00 10:30 5/25/2018 5/25/2018 0.25 INTRM2 CSGDRL CIRC P Shoot MWD survey. SPR's 8,995.0 8,995.0 10:30 10:45 5/25/2018 512512018 0.25 INTRM2 CSGDRL REAM P W&R f/8,995 to 9,000'w/250 gpm / 8,995.0 9,000.0 10:45 11:00 1830 psi, 30 rpm / 9 k trk 5/25/2018 5/2512018 1.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,000'to 9,047' 9,000.0 9,047.0 11:00 12:00 MD / 7,212' TVD, ADT 1.0 Hrs, ECD 11.62 ppg, 250 gpm, 1880 psi, PU wt 260 k, SO wt 200 k, ROT wt 220 k, 35 rpm, 10.5/9 k trq, WOB 2/7 k, MPD on connections. (Reduced mud wt from 10.8 ppg to 10.3 ppg) Page 9147 ReportPrinted: 7/16/2018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sun Depm start Time End nrne Dur frin Phsee Op Code Ad", Code Time P -T -X Operation (MRS) End WPM MKB) 5125/2018 5/2612018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL (19,047' to 9,453' 9,047.0 9,453.0 12:00 00:00 MD / 7,487' TVD, ADT 11.4 Hrs, ECD 11.4 ppg, 650 gpm, 2700 psi, ROT wt 220 k, 35 rpm, 13/10 k trq, WOB 2113 k, MPD on connections. 5/26/2018 5/26/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,453' to 9,968' 9,453.0 9,968.0 00:00 12:00 MD / 7,754' TVD, ADT 10.7 Hrs, ECD 11.6 ppg, 650 gpm, 2760 psi, ROT wt 220 k, 50 rpm, 13.5/8.5 k trq, WOB 4/8k, MPD on connections. 5/26/2018 5/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDL f/9,968' to 10,488' 9,968.0 10,488.0 12:00 00:00 MD / 7,911' TVD, ADT 10.7 Hrs, ECD 11.46 ppg, 650 gpm, 2790 psi, ROT wt 223 k, 50 rpm, 12.5/9 k trq, WOB 5116 k, MPD on connections. 5/2712018 5/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDLf/10,488'to 10,961' 10,488.0 10,961.0 00:00 12:00 MD 17,980' TVD, ADT 11.1 Hrs, ECD 11.42 ppg, 650 gpm, 2760 psi, ROT wt 225 k, 50 rpm, 15/11.5 k trq, WOB 5/10 k, MPD on connections. 5/27/2018 5/2712018 10.00 INTRM2 CSGDRL DCSG P Drill ahead w/SDLf/10,961'to TO 10,961.0 11,225.0 12:00 22:00 11,225' MD / 8,014' TVD, ADT 9.3 Hrs, ECD 11.41 ppg, 650 gpm, 2760 psi, ROT w1230 k, 50 rpm, 22/10 k trq, WOB 2/14 k, MPD on connections. (Drilled to 11,211', Closed reamer & cont. to drill to TO of 11,225', 8-3/4" hole @ 11,164') 5/27/2018 512812018 2.00 INTRM2 CEMENT CIRC P Close ribs on Autotrack, Pump up final 11,225.0 11,225.0 22:00 00:00 survey. Start weighting up from 10.3 ppg to 10.6 ppg w1700 gpm / 3000 psi. 5/28/2018 5/28/2018 2.00 INTRM2 CEMENT CIRC P Cont. to wt up to 10.8 ppg. w/700 - 11,225.0 11,225.0 00:00 02:00 525 gpm / 2960 - 1920 psi. Maintaining ECD's 11.5 - 11.6 ppg. 5128/2018 5/28/2018 0.75 INTRM2 CEMENT CIRC P Pump w/2 bpm / 550 psi. Attempt to 11,225.0 11,225.0 02:00 02:45 work liner. PU to 415 k with no movement. Slack off to 230 k. Drop 1.75" OD ball. Slack off to 200 k. Pump ball down w/2 bpm 1550 psi. Ball on seat @ 408 stks. Slack off to 190 k. Pressure up to 3510 psi & shear ball off seat. Pick up & confirm liner released. PU wt 225 k. (7" shoe 11,164' / TOL 8,666') 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT PMPO P Pump BHA out of open hole w/2 bpm / 11,225.0 11,150.0 02:45 03:00 500 psi. PU wt 225 k 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT CIRC P Circ& cond liner annulus w/330 gpm/ 11,150.0 11,150.0 03:00 03:30 2600 psi. 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT OWFF P F/C (static) 11,150.0 11,150.0 03:30 04:00 5128/2018 5/28/2018 1.00 INTRM2 CEMENT CIRC P Obtain SPR's. Apply back pressure & 11,150.0 11,055.0 04:00 05:00 check to see if Boats holding. Floats not holding. Pump 35 bbl 12.8 ppg dry job. Rack back 1 stand (/11,150' to 11,055' 5/28/2018 5/28/2018 4.75 INTRM2 CEMENT SMPD P Strip OOH f/11,055'to 2,766'. Floats 11,055.0 2,766.0 05:00 09:45 not holding. Dry job allowed us to not have to screw into each stand, but half of the stand was still wet pipe. 5128/2018 5/28/2018 0.25 INTRM2 CEMENT -5W—FF P FIC (static) 2,766.0 2,766.0 09:45 10:00 528/2018 5/28/2018 0.25 INTRM2 CEMENT MPDA P Pull RCD bearing & install trip nipple. 2,766.0 2,766.0 10:00 10:15 Page 10/47 ReportPrinted: 7 /1 612 01 8 Gperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Start Time End Time our (hr) phase op Code Activity code Time P -T -X Operation rIKS) End Depth (Wa) 5/28/2018 0.25 INTRM2 CEMENT TRIP P POOH f/2,766'to 2,582' 2,766.0 2,582.0 10:30 5/28/2018 0.75 INTRM2 CEMENT BHAH P UD float sub, stabilizer, flow diverter & 2,582.0 2,538.0 11:15 liner running tool. C/O handling r13:00 equipment to 4" 5/28/2018 1.75 INTRM2 CEMENT TRIP P POOH & rack back 4" DP f/2,538' to 2,538.0 159.0 13:00 159' 5/28/2018 0.50 INTRM2 CEMENT BHAH P Clean & clear floor of excess BHA 159.0 159.0 13:30 tools & equipment. 5/28/2018 5/28/2018 1.50 INTRM2 CEMENT SHAH P UD BHA #4 as per Baker reps. 159.0 0.0 13:30 15:00 5/28/2018 5/2812018 0.50 INTRM2 CEMENT SHAH P Clean & clear floor of excess BHA 0.0 0.0 15:00 15:30 tools & equipment. 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT RURD P Mobilize casing tools & equipment to 0.0 0.0 15:30 16:00 rig floor. R/U power tongs. 5/28/2018 5/28/2018 0.25 INTRM2 CEMENT BHAH P M/U K-1 cement regr 0.0 0.0 16:00 16:15 reps. 5/28/2018 5/28/2018 1.75 INTRM2 CEMENT TRIP P RIH with retainer to 2,532' 0.0 2,532.0 16:15 18:00 5/28/2018 5/28/2018 0.50 INTRM2 CEMENT PUTS P M/U 10.59' pup, SLZXP & anchor assy 2,532.0 2,571.0 18:00 18:30 as per Baker reps to 2,571' (utilized casing tongs & torque tum for packer & anchor assy connection) 5/28/2018 5/28/2018 1.00 INTRM2 CEMENT CIRC P Break circ & stage flow rate up to 4 2,571.0 2,571.0 18:30 19:30 bpm 1260 psi.. SIMOPS UD casing tools & equipment. 5/28/2018 5/29/2018 4.50 INTRM2 CEMENT TRIP P RIH cement retainer / linerto acr keSO 2,571.0 7,563.0 19:30 00:00 assy wit 71' 10 7,563'. wt 155 k. Disp Calc 50 bbls /Act 50 bbls 5129/2018 5/29/2018 0.75 INTRM2 CEMENT TRIP P Trip in hole with SDL run #2 7,563.0 8,597.0 00:00 00:45 cementing BHA from 7,563' MD to 8,597' MD. P/U=195k S/0=168k. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT WASH P Wash down through liner top from 8,597.0 8,692.0 00:45 01:15 8,597' MD to 8.692' MD @ 1 bpm, 210 psi. Blow down top drive. 5/29/2018 5/29/2018 2.75 INTRM2 CEMENT TRIP P Continue RIH from 8,692' MD to 8,692.0 11,083.0 01:15 04:00 11,083' MD. P/U=230k, S/0=188k. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT RURD P M/U BOT cement swivel, cement hose 11,083.0 11,083.0 04:00 04:30 and 1502 equipment. 5/29/2018 5/29/2018 0.25 INTRM2 CEMENT CIRC P Establish circulation Q 3 bpm, 500 psi 11,083.0 11,083.0 04:30 04:45 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT WASH P Wash down from 11,083'10 11,109' 11,083.0 11,110.0 04:45 05:15 MD @.5 bpm, 250 psi. Observe pressure increase to 270 psi w/ 3k WOB (Locate seals). P/U and break over, SIO to 11,110' and confirm. Good circulation on 8-3/4" x 7" annulus Q .5 bpm, 270 psi. 5129/2018 5/29/2018 0.25 INTRM2 CEMENT RURD P Make up 5'space out pup, slack off 11,110.0 11,113.0 05:15 05:30 and no-go out @ 11,113' MD with bleeders open. S/0 and set down 10k, P/U and observe 10k overpull. S/0 30k, PIU 20k over to confine anchor latched. Slack off to 5k down. 5/29/2018 5/29/2018 5.50 INTRM2 CEMENT CIRC P Circulate and condition, stage up 11,113.0 11,113.0 05:30 11:00 from .5 bpm 280 psi to 4 bpm 830 psi. Partial packoff @ 4650 silks into bottoms up from 830 to 1070 psi, did not lose returns. Reduce rale to 1 bpm to stabilize. 5/29/2018 5/29/2018 1.00 INTRM2 CEMENT CIRC P Circulate and condition @ 1 bpm, 380 11,113.0 11,113.0 11:00 12:00 psi. Page 11/47 Report Printed: 711612018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Tim End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (Wls) 5/29/2018 5/29/2018 2.50 INTRM2 CEMENT CIRC P Continue staging up circulating rate 11,113.0 11,113.0 12:00 14:30 from 1 bpm 380 psi to 2 bpm, 450 psi FCP. 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT HOSO P Drop/Pump down 1.75" release ball, 11,113.0 11,113.0 14:30 16:00 pump down @ 2 bpm 420 psi. Ball on seat @ 36 bbl away. Set down 1Ok. Pressure up to 4000 psi hold 1 min. Bleed off slowly to 400 psi. Pressure up and shear out ball seat @ 890 psi, observe pressure bleed off. Break circulation @ 1 bpm, 300 psi. P/U 10' @ 225k, liner released. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT MPSP P_ Set K1 cement retainer per Baker rep., 11,113.0 11,113.0 16:00 16:30 14 turns to right @ 5 rpm 4k Tq. Set down 30k. P/U and observe slips set. Pull 10k over, set down 30k. P/U to neutral 21 Ok and un -sting. P/U 10'@ 225k, free from retainer. Set down and sling back in with 5k. Break circulation @ 1 bpm, 330 psi. 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT PUCM P PJSM and pump 7" liner cement per 1,113.0 11,113.0 16:30 18:00 program, Flood lines, test to 4000 psi. .(� Pump 20 bbl 11.4 ppg Mud Push @ 2 CAM./� bpm, 400 psi. Pump 32.4 bbl 12.4 ppg Lead cement @ 1.8 bpm, 193 psi µ. followed by 26 bbl 15.8 ppg tail cement @ 1.9 bpm, 46 psi. Chase Nth 20 bbl water @ 1.9 bpm, 11 psi. 5/29/2018 5/29/2018 1.50 INTRM2 CEMENT CMNT P Displace cement with rig pump, 10.7 11,113.0 11,113.0 18:00 19:30 ppg LSND @ 2 bpm, 630 psi for 128.3 bbl, reduce to 1 bpm 490-590 psi for final 20 bbl. Total displacement 146.8 bbl. CIP @ 19:30 hrs. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT PACK P Un -Sting from cement retainer, P/U 22' 11,113.0 11,113.0 19:30 20:00 to expose packer setting dog sub. Slack off and set 50k down, observe packer shear / set. P/U, establish rotary @ 15 rpm, 2k Tq. Set down 50k while rotating, repeat. SLZX Packer set, TOL 8,630' MD. 5/29/2018 5/29/2018 1.00 INTRM2 CEMENT CIRC P P/U to 11,076' MD with running tool, 11,113.0 11,076.0 20:00 21:00 circulatestring, liner and hole clean of cement @ 8 bpm, 1300 psi. Observe increase in pH of mud returns and cement contamination from 450 ON away. (Liner top). Pumped total 580 bbl. 5/29/2018 5/29/2018 0.50 INTRM2 CEMENT OWFF P Monitor well static 30 minutes. 11,076.0 11,046.0 21:00 21:30 SIMOPS- Lay down 2 singles and cement swivel assembly. 5/29/2018 5/30/2018 2.50 INTRM2 CEMENT TRIP P POOH on elevators, racking back 5" 11,046.0 8,971.0 21:30 00:00 DP from 11,046' MD to 8,971' MD. P/U=220k, correct hole fill. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT TRIP P Pull out on elevators from 8,971' MD 8,971.0 8,690.0 00:00 00:15 to 8,690' MD racking back stands. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT PMPO P Pump out from 8,690' MD to 8,595' 8,690.0 8,595.0 00:15 00:45 MD @ 350 gpm, 840 psi to flush across the liner top tie back extension. Page 12147 Report Printed: 7/16/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (m) Phase Op Code Activity Code Time NTA Operation (ftKB) End Depth mKB) 5/30/2018 5/30/2018 0.75 INTRM2 CEMENT CIRC P Pump 20 bbl water pill, circulate S-S 8,595.0 8,595.0 00:45 01:30 @ 650 gpm, 2190 psi. Treating cement contamination in active system. Obtain SPR's, complete circulation with 20 bbl 12.2 ppg slug in pipe. Blow down top drive, P/U=215k, S/0=165k. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow, static. 8,595.0 8,595.0 01:30 01:45 5/30/2018 5/30/2018 1.00 INTRM2 CEMENT PULD P POOH laying down 5" DP from 8,595' 8,595.0 7,635.0 01:45 02:45 MD to 7,635' MD, hole fill becoming erratic. Stop to observe. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT OWFF T Monitor for flow, observe extremely 7,635.0 7,635.0 02:45 03:00 aired up mud flowing. Treat trip lank with De-foamer. Pull 1 joint without hole fill pump on, observe fluid level falling properly. 5/30/2018 5/30/2018 5.00 INTRM2 CEMENT PULD P Continue POOH from 7,635' MD to 7,635.0 2,480.0 03:00 08:00 2,480' MD, laying down 5" DP and Leaning cement rings. Proper hole fill. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT BHAH P Flow check static, Function annular, 4- 2,480.0 2,480.0 08:00 08:30 1/2" x 7" UPR and 3-1/2" x 6" LPR. Lay down Baker liner running tool to 2,439' MD. Swap to 4" elevators. 5/30/2018 5/30/2018 1.25 INTRM2 CEMENT TRIP P POOH, racking back 4" DP in derrick. 2,480.0 0.0 08:30 09:45 Lay down Baker cement retainer running tools. Trip Calc Fill=85.42 bbl, Actual Fill=86 bbl. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT PRTS P Function blind rams. R/U and pressure 0.0 0.0 09:45 10:15 lest 7" Liner top packer to 1000 psi for 10 minutes on chart. 5/30/2018 5/30/2018 1.00 INTRM2 CEMENT SLPC P PJSM, RIH to 95' and hang blocks. 0.0 95-0- 10:15 11:15 Cut and slip 60' drilling line. (SIMOS- C/O lop drive stabilizer) 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT SVRG P Service lop drive and draworks. C/O 95.0 95.0 11:15 11:45 oil filler on draworks. 5/30/2018 5/30/2018 0.25 INTRM2 CEMENT BHAH P POOH from 95'. Lay down Baker tools 95.0 0.0 11:45 12:00 and equipment via Beaverslide. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT RURD P Clean and clear rig floor, Mobilize 0.0 0.0 12:00 12:30 casing equipment to rig floor. 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT RURD P FMC pull wear bushing. 0.0 0.0 12:30 13:00 5/30/2018 5/30/2018 0.50 INTRM2 CEMENT RURD P Rig up casing equipment. 0.0 0.0 13:00 13:30 5/30/2018 5/30/2018 10.25 INTRM2 CEMENT PUTB P PIU 7" Baker Bullet seal asst' PIU and 0.0 8,615.0 13:30 23:45 run 7" 26# BTCM tie-back casing string per detail to 8,615' MD. (203 jts) IU= 240k, S/0=175k. Pumped 40 bbl 12.8 ppg slugs @ 1,509', 5,104' and ` 7,519' due mud running over pipe while RIH. Calc and actual displacement=80 bbl. 5130/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Rig up circ head on it #204, continue 8,615.0 8,655.0 23:45 00:00 RIH to 8,655' MD to locate TOL. 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Continue RIH with Jt#205 and No-Go 8,655.0 8,660.0 00:00 00:15 with 1 Ok @ 8,659.88' MD. Calculate space out. 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT PRTS P Close annular preventer, pump down 8,660.0 8,660.0 00:15 00:30 kill line and pressure test 9-5/8" x 7" annulus (with rasing side open) 1000 psi to confirm seals engaged. Page 13/47 Report Printed: 7/1612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Damm Start Tim End Time our (W) Phase op Code Activity Code Time P -T -X operetlan (fd(B) End Depen MKS) 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Pick up 22' and pull seals out, pump 2 8,660.0 8,642.0 00:30 00:45 bpm 50 psi, slack off to locate TOL with seals. Observe pressure up 8,640' and returns stopped @ 8,642' MD, holding 350 psi not bleeding down. Verify space out. 5/3112018 5/31/2018 0.75 INTRM2 CEMENT HOSO P Lay down 3 joints, swap #203 for #205 8,642.0 8,573.0 00:45 01:30 1 1 for space out to 8,573' MD. 5/31/2018 513112018 0.50 INTRM2 CEMENT HOBO P Make up BTCM-H563 XO joint, 8,573.0 8,573.0 01:30 02:00 hanger and pup, landing joint. Rig up circulating swedge and cement line. P/U=240k, S/0=1 75k 5/31/2018 5/31/2018 0.25 INTRM2 CEMENT HOSO P Pump 1.5 bpm 50 psi, slack off to 8,573.0 8,639.0 02:00 02:15 observe seals engaging @ 8,640' to verify space out. Pick up and break over, slack off to 8,639' putting hanger just below annular preventer. Rig up to reverse in Cl brine and diesel FP. 5/31/2018 5/31/2018 1.25 INTRM2 CEMENT CIRC P Reverse circulate @ 3 bpm, circulating 8,639.0 8,639.0 02:15 03:30 out 3 slugs in pipe. SIMOPS- Rig up Ball Mill to pump diesel, pressure test. Rig down casing power tongs. PJSM on brine/diesel displacement. 5/31/2018 5131/2018 2.00 INTRM2 CEMENT FRZP P Reverse in 30.5 bbi 9.7 ppg HV fresh 8,639.0 8,639.0 03:30 05:30 water spacer, 203 bbl 8.6 ppg Corrosion inhibited seawater. Swap to Ball Mill pump for 42 bbl 6.8 ppg diesel (LEPD) freeze protect @ 2 bpm. Final SIP 1128 psi. 5/3112018 5131/2018 0.25 INTRM2 CEMENT HOSO P Slack off stripping through annular, 8,639.0 8,653.8 05:30 05:45 sting in seals for 6'. Bleed off pressure from kill line. Continue slacking off and land 7" hanger @ 8,653.79' Bullet Seal depth. (6.09' off of fully located). 5/3112018 5/31/2018 0.50 INTRM2 CEMENT RURD P Verify pressure bled off, open annular 8,653.8 0.0 05:45 06:15 preventer. Rig down circulating swedge, blow down lines. Back out and lay down 7" landing joint.. Rig down casing elevators. 5/31/2018 5/31/2018 1.25 INTRM2 CEMENT W WSP P FMC set 7" pack -off. R/U and test 0.0 0.0 06:15 07:30 pack -off to 250/5000 psi for 5115 minutes good. SIMOPS- Lay down 5" subs, equipments. P/U 4" handling equipment and subs. Prep tools for / ram change. 5/31/2018 5/31/2018 1.75 INTRM2 CEMENT PRTS P Rig up and test 9-5/8" x 7" annulus to— 0.0 0.0 2500 psi for 30 minutes charted, good. 07:30 0915 Blow down and dg down. 5131/2018 5/31/2018 1.75 INTRM2 CEMENT BOPE P Change out upper VBR's from 4-1/2" x 0.0 0.0 09:15 11:00 7" to 3-1/2" x 6". SIMOPS- Change out saver sub from 5" NC50 to 4" XT39. 5131/2018 5/31/2018 1.00 INTRM2 WHDBOP RURD P Rig up to test ROPE. Fill stack, choke 0.0 0.0 11:00 12:00 manifold, choke and kill lines with water. Purge air from system. Page 14147 Report Printed: 7/1 612 01 8 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(m) Phase Op Code Acbv"Code Time P -T -X Operation (ftKB) End Depth (WB) 5/31/2018 5/31/2018 4.25 INTRM2 WHDBOP BOPE P Perform AOGCC BOPE test, 250/3500 0.0 0.0 12:00 16:15 psi 5 min ea. AOGCC Lou Laubenstien (5/29 12:43) and SLIM Mutasim Elganzoory (5/29 14:00) waived witness via email. 4" Test joint, tested Annular preventer, 4" Demco kill, Choke valves #1,12,13,14, Upper IBOP, Upper 3'/V x 6" VBR, HCR Kill. CV #9,11, Manual IBOP, CV# 5, 8,10, XT39 Dart valve. CV# 4, 6, 7, XT39 FOSV, CV# 2, HCR choke, manual choke and kill, lower 3W" x 6" VBR. Swap to 4XV Test joint, test annular preventer, Upper and lower VBR's, 5/31/2018 5/31/2018 0.25 INTRM2 WHDBOP BOPE P Perform accumulator function test. 0.0 0.0 16:15 16:30 System pressure=3050 psi. Pressure after functioning all rams, annular and HCR's=1400 psi. 200 psi attained= 29 seconds with electric pump. Full system recovery=178 seconds with electric and air pumps.4 bottle N2 average=2200 psi. 5/31/2018 5/31/2018 0.50 INTRM2 WHDBOP BOPE P Pull test joint, test Blind rams to 0.0 0.0 16:30 17:00 250/3500 psi 5 min each charted, tested manual and super auto choke Vo 1100 psi. 5/31/2018 5/31/2018 1.00 INTRM2 WHDBOP RURD P Rig down test equipment, pull test 0.0 0.0 17:00 18:00 plug. Set 6.125" ID wear bushing. 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT SVRG P Inspect and service top drive, blocks 0.0 0.0 18:00 18:30 and hook. 5/31/2018 5/31/2018 0.50 INTRM2 CEMENT SHAH P PJSM, Mobilize BHA tools and 0.0 0.0 18:30 19:00 components to rig floor. 5/31/2018 5/31/2018 1.00 INTRM2 CEMENT SHAH P M/U 6" Rock bit / Zero bend motor 0.0 227.0 19:00 20:00 cleanout BHA#5 to 227' MD per Baker rep. 5/31/2018 6/1/2018 4.00 INTRM2 CEMENT PULD P Single in hole from 227' MD to 4,000' 227.0 4,000.0 20:00 00:00 MD with 14# WearKnot drill pipe from pipe shed. P/U=112k, 8/0=100k. Annulus C= 70 psi, Annulus B= 120 psi @ 22:00 hrs. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT PULD P Continue picking up 4" 14# WearKnot 4,000.0 4,509.0 00:00 01:00 pipe from pipe shed, running in 4,000' MD to 4,509' MD filling pipe every 20 stands. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT TRIP P Trip in hole from 4,509' MD to 7,092' 4,509.0 7,092.0 01:00 02:00 1 1 1 MD with 4" 14# DP out of derrick. 6/1/2018 6/1/2018 4.00 INTRM2 CEMENT PULD P Continue singling in hole, picking up 4" 7,092.0 10,903.0 02:00 06:00 15.7# DP from pipe shed 7,092' MD to 10,903' MD filling every 20 stands. Observed string lake -81k briefly while RIP @ 8,663' MD. 6/1/2018 6/1/2018 0.75 INTRM2 CEMENT CIRC P Circulate 1 string volume @ 10,903' 10,903.0 10,903.0 06:00 06:45 MD 210 gpm, 1660 psi. 6/1/2018 6/1/2018 1.50 INTRM2 CEMENT PRTS P Rig up and test casing to 3500 psi for 10,903.0 10,903.0 06:45 08:15 P mmuteb s Carte , testing tie back string and SDL liner. 6/1/2018 6/1/2018 1.25 INTRM2 CEMENT COCF P Wash and ream down to cement 10,903.0 11,103.0 08:15 09:30 retainer @ 200 gpm, 1560-1180 psi, 8- 98 Tq. Tag firm cement Q 11,102.5' MD. P/U=215k, S/0=143k, ROT=162k. Page 16147 ReportPrinted: 711612018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Corte Activity Code Time P -T -X Operation (ftKB) End Depth (WS) 6/1/2018 6/1/2018 2.50 INTRM2 CEMENT DRLG P Drill out cement cement retainer and 11,103.0 11,130.0 09:30 12:00 shoe track from 11,103' MD to 11,130' VID @ 200 gpm, 1330 psi, 90 rpm, 9.5k Tq. SIMOPS- L/D 4 stands 5" DP with tugger and mousehole. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT DRLG P Continue drilling shoe track and 11,130.0 11,225.0 12:00 13:00 rathole from 11,130' MD to 11,225' MD. 6/1/2018 6/1/2018 1.00 INTRM2 CEMENT DDRL P Drill new formation from 11,225' MD to 11,225.0 11,236.0 13:00 14:00 11,236' MD, 8,015' TVD. ADT=.6. P/U=225k, S/0=140k, ROT=164k, Tq on/off=11 k/10k. Note: Stopped drilling due low ROP and differential pressure to avoid bit destruction and potentail fishing trip. 6/1/2018 6/1/2018 0.50 INTRM2 CEMENT TRIP P POOH from 11,236' MD to 11,093' 11,236.0 11,093.0 14:00 14:30 MD, 6/1/2018 6/1/2018 1.50 INTRM2 CEMENT CIRC P Circulate and condition @ 210 gpm, 11,093.0 11,093.0 14:30 16:00 1250 psi, 50 rpm, 8k Tq. Recipricate from 11,093' MD to 10,998' MD. CBU x 1.5. Obtain SPR's. 6/1/2018 6/1/2018 0.50 INTRM2 CEMENT OWFF P Monitor well for flow, static 30 minutes. 11,093.0 11,093.0 16:00 16:30 6/1/2018 6/1/2018 6.50 INTRM2 CEMENT TRIP P POOH on elevators from 11,093' MD 11,093.0 318.0 16:30 23:00 to 318' MD. P/U=75k. Calc fill for trip=70 bbl, Actual fill=74 bbl. Observed brief 5-10k overpull @ 8,865'-8,862' MD 6/112018 6/1/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow, static. 318.0 318.0 23:00 23:15 6/1/2018 6/2/2018 0.75 INTRM2 CEMENT BHAH P Rack back last stand, rack back 318.0 0.0 23:15 00:00 HWDP/Jars, L/D BHA#5 from 318' MD. Annulus C= 70 psi, Annulus B= 340 psi @ 22:00 hrs. 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT SHAH P Clean and clear rig floor of BHA#5 0.0 0.0 00:00 00:15 tools. Mobilize BHA#6 tools to rig floor. 6/2/2018 6/2/2018 2.75 INTRM2 CEMENT BHAH P PJSM, M/U BHA#6 to 336' MD per 0.0 336.0 00:15 03:00 1 Baker DD/ MWD. (Upload sources.) 6/2/2018 6/2/2018 0.75 INTRM2 CEMENT TRIP P Trip in hole from 336' MD to 2,238' MD 336.0 2,238.0 03:00 03:45 out of derrick. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT DHEQ P Fill pipe, establish circulation and 2,238.0 2,238.0 03:45 04:45 shallow pulse test BHA 6 @ 200-250 gpm, 970-1400 psi, 25 rpm, 1.2k Tq, P/U=98k, S/0=95k, ROT=93k. 6/2/2018 6/2/2018 5.25 INTRM2 CEMENT TRIP P Trip in hole from 2,238' MD to 11,108' 2,238.0 11,108.0 04:45 10:00 MD out of derrick, filling pipe every 20 stands. P/U=215k, S/0=135k, ROT= 158k, 50 rpm @ 10k Tq, 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT OWFF P OWFF static, slightly aired up. 11,108.0 11,108.0 10:00 10:15 SIMOPS- PJSM on installing RCD. 6/2/2018 6/2/2018 0.50 INTRM2 CEMENT MPDA P Remove trip nipple, install RCD 11,108.0 11,108.0 10:75 10:45 bearing with 1 Natural and 1 Poly element. 6/2/2018 6/2/2018 1.25 INTRM2 CEMENT DLOG P Establish circulation @ 180 gpm, 1270 71,108.0 11,220.0 1045 12:00 psi. Break in bearing @ 50 rpm, 9.8k for 2 minutes. Perform MAD pass, logging from 11,112' MD to 11,220' MD @ 200 gpm, 1900 psi, 75 rpm, 10k Tq. Log @ 150 fph. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT REAM P Wash and ream down from 11,220' 11,220.0 11,236.0 12:00 13:00 MD to 11,236' MD Page 16/47 ReportPrinted: 7/16/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Advity Code Time P -T -X Operaeai (ftKB) EM Depth (ftKB) 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT DDRL P Drill new formation from 11,236' MD to 11,236.0 11,245.0 13:00 13:15 11,245' MD 6/2/2018 6/2/2018 0.25 INTRM2 CEMENT TRIP P POOH from 11,245' MD to 11108' 11,245.0 11,108.0 13:15 13:30 MD. P/U=230k, S/0=125k. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT CIRC P Circulate and condition for FIT @ 200 11,108.0 11,108.0 13:30 14:30 gpm, 1700 psi, 100 rpm, 9k Tq. Circulate 10.6 ppg in and out. 6/2/2018 6/2/2018 1.00 INTRM2 CEMENT FIT P Rig up and perform FIT to 12.5 ppg 1 L 08.0 11,108.0 14:30 15:30umpe pm o 770 psi. Rig down test equipment. 6/212018 612/2018 1.00 PROD1 DRILL DLOG P Wash down, logging from 11,108' MD 11,106.0 11,245.0 15:30 16:30 1 to 11,245' MD @ 200 gpm, 150 fph. 6/2/2018 6/212018 1.50 PROW DRILL DISP P PJSM, Displace well from 10.6 -SND 11,245.0 11,245.0 16:30 18:00 to 8.5 ppg MOBM per plan. Pumped 40 bbl DeepClean spacer, 75 bbl HV OBM followed by 376 bbl 8.5 ppg MOBM @ 5 bpm. Rotate 100 rpm, 101k Tq, reciprocate from 11,245' MD to 11,203' MD. Maintain 10.5 ppg EMW with MPD as 8.5 ppg mud comes around annulus. 6/212018 6/2/2018 0.50 PROD1 DRILL PMPO P Pump out of hole from 11,245' MD to 11,245.0 11,108.0 18:00 18:30 11,108' MD @ 200 gpm, 1900 psi. P/U=200k. 6/2/2018 6/212018 0.50 PROD1 DRILL OWFF P Rig up and fingerprint formation. Shut 11,106.0 11,108.0 18:30 19:00 down pump, trapping 422 psi. Open choke for 20 seconds, shut in 5 min build to 65 psi. Open choke for 20 seconds, shut in 5 min build to 43 psi. Open choke for 2 min, shut in 5 build to 38 psi. Gained 1 bbl in trip tank. Formation pressure between 8.5 and 8.6 ppg. (Note: 400-500 units gas on bottoms up) 612/2018 6/2/2018 0.50 PR0D1 DRILL REAM P Wash and ream down from 11,108' 11,108.0 11,245.0 19:00 19:30 MD to 11,245' MD @ 200 gpm, 1930 psi, 100rpm, 9k Tq. Obtain SPR's. 6/2/2018 6/312018 4.50 PROD1 DRILL DDRL P Directional Drill from 11,245' MD to 11,245.0 11,679.0 19:30 00:00 11,679' MD, 8,067' TVD. ADT=3.4 hrs, P/U=200k, S/0=125k, ROT=165k, 140 rpm, Tq on/off=10k/9k. 200 gpm, 2000 psi, 9.8 ppg ECD. Holding 230 psi annular pressure during connections (9.0 ppg) dynamically. Annulus C= 70 psi, Annulus B= 620 psi @ 22:00 hrs. 6/312018 613/2018 3.50 PROD1 DRILL DDRL P Directional Drill from 11,679' MD to 11,679.0 12,037.0 00:00 03:30 12,037' MD, 8,044' TVD in Kingak shale. ADT=2.6 hrs, P/U=240k, S/0=110k, ROT=170k, 140 rpm, Tq on/off-8.5k/6k. 200 gpm, 2000 psi, 9.8 ppg ECD. Holding 300 psi annular pressure during connections (9.3 ppg) dynamically. Observe steadily rising and erratic ECD along with pump pressure. Page 17147 ReportPrinted: 7116/2018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operabon (ftKB) End Depth(ftKB) 6/3/2018 6/3/2018 1.00 PROD1 DRILL BKRM T Attempt to backream stand from 12,037.0 11,965.0 03:30 04:30 12,037', packing off @ 200 gpm, 2700 psi. Stall out string @ 11,966' MD 100 rom,m 15k Tq. Drop back down to 12,021' re-attempt to backream, observe packing off 3 times @ 4 bpm, 1200 psi. Bleed off pressure, continue attempts to pump @ 1-2 bpm. Rack back stand @ 11,965' MD. 6/3/2018 6/3/2018 1.00 PROD1 DRILL SMPD T Strip out stand due packing off while 11,695.0 11,870.0 04:30 05:30 attempting to pump. Apply 300 psi annular pressure, pull stand from 11,965' MD to 11,870' MD, PIW255- 270k.. Work stand up @ 2751k max, drop down and re-pull @ 255k, stand back stand #122. 6/3/2018 6/3/2018 6.50 PROD1 DRILL CIRC T Makeup single on top of stand #122, 11,870.0 11,870.0 0530 12:00 attempt to establish circulation 5-1.5 bpm, 600-1050 psi, 20 rpm, 6.5-7.5k C�(V` Tq. ROT=170k. Observe packing off and torque with any pipe movement, or any attempt to increase in Flow rate. "Discuss with engineering, establish plugback plan for Kingak shale section. 6/3/2018 6/3/2018 2.50 PROD1 DRILL CIRC T Continue attemping to establish 11,870.0 11,870.0 1200 14:30 circulation @ <1 bpm, rotating 20-50 rpm 7-11k Tq, @ 11,870' MD, intermittantly stalling out. Attempting to work string up hole. Increase back pressure to 500 psi, holding 500-700 psi string pressure. 6/3/2018 6/3/2018 0.50 PROD1 DRILL OTHR T While rotating 20 rpm 14k Tq @ 11,870.0 11,870.0 1430 15:00 11,870' MD, observe torque increase to 18k and stall. Release trapped torque, attempt to slack off down to 75k, no-go, P/D 325k, no-go. Torque to 14k and slump, no movement, no rotation, no circulation. Holding 300 psi on annulus. 6/3/2018 6/4/2018 9.00 PROD1 DRILL JAR T Attempting to free string, alternating 11,870.0 11,870.0 15:00 00:00 ,/ jarring up @ 300k, straight pull 430k /max. Bumper sub down to 100k, then S/O to 75k. Reduce back pressure to 300psi. Periodically apply 500-800 psi on drillstring on the up stroke. No movement, circulation or rotary. Stuck @ 11,870' MD. Annulus C= 70 psi, Annulus B= 200 psi @ 22:00 hrs. 6/4/2018 6/4/2018 0.50 PROD1 DRILL SFTY T Service blocks, top drive and crown. 11,870.0 11,870.0 0000 00:30 j Perform post jarring derrick inspection. 6/4/2018 6/4/2018 6.00 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 0030 06:30 alternating jarring up @ 300k, straight pull 430k max. Bumper sub down to 100k, then S/O to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drilistring on the up stroke. No movement, circulation or rotary. 6/4/2018 6/4/2018 0.50 PROD1 DRILL SFTY T Service blocks, top drive and crown. 11,870.0 11,870.0 06:30 07:00 Perform post jarring derrick inspection. Page 18(47 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log shin Depth Start Time End Time Dur (hr) Phase Op Code Activity Code JAR Time P -T -X T Openoon Continue attempting to free string, (WB) 11,870.0 End Deprh(MR 11,870.0 6/4/2018 6/4/2018 2.50 PROD1 DRILL 0700 09:30 alternating jarring up @ 300k, straight pull 440k max. Bumper sub down to 100k, then S/0 to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drillstring on the up stroke. No movement, circulation or rotary. 6/4/2018 6/4/2018 1.50 PROD1 DRILL SFTY T Service draworks, blocks, lop drive 11,870.0 11,870.0 0930 11:00 and crown. Perform post jarring derrick inspection. 6/4/2018 6/4/2018 1.00 PRODI DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 11:00 12:00 alternating jarring up @ 300k, straight pull 440k max. Bumper sub down to 100k, then S/0 to 75k. Maintain 300psi annular pressure. Periodically apply 500-800 psi on drillstring on the up stroke. Put 15k torque in string and work down, release torque. No movement, circulation or rotary. Install TIW valve on top of stand #121. 6/4/2018 6/4/2018 3.00 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 1200 15:00 alternating jarring up @ 250-275k, straight pull 375k. Bumper sub down to 100k. Maintain 300psi annular pressure. 6/4/2018 6/4/2018 0.50 PROD1 DRILL CIRC T Rig up and perform injectivity test 11,870.0 11,870.0 15:00 15:30 down drill string with 8.5 ppg MOBM. Pump at .5 bpm, observe injection at 2860 psi. Stage rate up to 1 bpm, 2500 psi. SIMOPS- Weight up surface mud to 9.2 ppg kill weight. 6/4/2018 6/4/2018 3.50 PROD1 DRILL CIRC T Bullhead 9.2 ppg mud to bit @ .5-.7 11,870.0 11,870.0 15:30 19:00 bpm, 2720 psi. Total pumped 130 bbl. 6/4/2018 6/4/2018 1.50 PROD1 DRILL CPBO T PJSM with CPA[, Baker fishing and 11,870.0 11,870.0 19:00 20:30 DDI crew, begin blind back -off. Work string from 250k up to 130k down, 20' travel. Begin with 5k left hand torque and work down, stroke string 13x, add 1k LH Tq, stroke pipe 11x, add 1k, stroke 11x, add 11k stroke 15x, add 1k stroke 18x, add 1k for 10k total LH torque, 15 wraps. 6/4/2018 6/4/2018 0.50 PR0D1 DRILL CPBO T Work string 7x, on downstroke 11,870.0 4,880.0 20:30 21:00 observe string break out, free LH spin. Shut down, open TIW valve. P/U 3'@ 120k. Drill pipe pressure 160 psi with 9.2 ppg, Annular pressure 300 psi (applied) with 8.6 ppg. P/U 20' to circulate. 6/4/2018 6/4/2018 2.50 PROD1 DRILL CIRC T Pump 9.2 ppg mud up annulus, 4,880.0 11,870.0 21:00 23:30 maintaining constant DPP via MPD choke. Observe 9.2 ppg mud at surface @ 110 bbl pumped, indicating string backed off @ 4,900' MD (as well as 120k string wt). Continue pumping, weighting up to 9.8 ppg from surface to 4,900' MD (9.2 ppg equivalent @ shoe). FCP=770 psi. MPD chokes fully open after final weight up. Page 19/47 Report Printed: 711 612 01 8 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time our (hr) Phase Op Code Activity Code FISH Time P -T -X T Operabon Wash and ream down, screw back into (MB) 11,870.0 End Depth (WB) 11,870.0 6/4/2018 6/5/2018 0.50 TRD1 DRILL 2330 00:00 drill string. S/O rotating 5 rpm, 1.5k Tq, .5 bpm 240 psi. P/U=120k, S/0=110k. Locate top of fish, observe pressure build and 1-21K weight. Kill pump, SIC, and screw into string, stall @ 5k Tq. Work torque down from 120k to 110-k. Stage up string torque to 20k ft/lbs. Stroke string and work torque down. Pull test 175k. Bleed off DP pressure, begin flow check annulus - static. Annulus C= 70 psi, Annulus B= 190 psi @ 22:00 hrs. 6/5/2018 6/5/2018 0.75 PROM DRILL SFTY T F/C (static) Service blocks, top drive 11,870.0 11,870.0 00:00 00:45 and crown. Perform postjarring derrick inspection. MPD holding 50 psi on backside. 615/2018 6/5/2018 0.25 PROD1 DRILL RURD T Remove TIW valve. UD 2 its DP in 11,870.0 11,870.0 00:45 01:00 mouse hole., 6/5/2018 6/5/2018 14.50 PROD1 DRILL JAR T Continue attempting to free string, 11,870.0 11,870.0 01:00 15:30 alternating jarring up w/275 - 3001k, straight pull 440k max. Bumper sub down to 100k, then SID to 75k. SIMOPS - House keeping, work orders, & prep for E -Line. 6/5/2018 6/5/2018 6.00 PROD1 DRILL ELNE T Mobilize E -line tools & equipment to 11,870.0 11,870.0 15:30 21:30 rig floor. M/U FOSV & otis connection to stump. Spot E -line truck M/U & test E -Line tools on ground. 6-/5/2018 6/6/2018 2.50 PR0D1 DRILL ELNE T M. Hang E -Line sheave. R/U 11,870.0 11,870.0 21:30 00:00 logging head. M/U E -line BOPE to slump. Set lubricator in mouse hole. Test E -Line tools & tractor for compatibility. 6/6/2018 6/6/2018 3.00 PROD1 DRILL ELNE T Cont to test E -line & tractor assy. P/U 11,870.0 11,870.0 00:00 03:00 E -Line assy & M/U lubricator. Test to 3200 psi (good). M/U pert guns to tractor assy. 6/6/2018 6/6/2018 3.50 PROD1 DRILL ELNE T RIH w/2" perf gun tractor assy. Not 11,870.0 11,870.0 0300 06:30 able to work past 31'. POOH & inspect tolls. Nothing viably wrong with tools. Double check all OD's & ID's (good). M/U 2" weight bar drift assy & RIH. Had trouble running in hole for the first 800', then no issues. Cont. to RIH drift assy to 5,500'. Decision to POOH & RID E -line. E -Lin e hour'd out. 6/6/2018 616/2018 0.50 PROD1 DRILL ELNE T RID perf gun/tractor assy. RID E -line. 11,870.0 11,670.0 06:30 07:00 6/6/2018 6/6/2018 2.25 PROD1 DRILL JAR T MIU single jt of drill pipe & cont. to jar 11,870.0 11,870.0 07:00 09:15 on pipe 6/6/2018 6/6/2018 1.00 PROD, DRILL SLPC T Slip &cut 72' drill line 11,870.0 11,870.0 09:15 10:15 6/6/2018 6/6/2018 0.75 PROD1 DRILL SVRG T Sevice rig, top drive &draw works 11,870.0 71,870.0 1015 11:00 6/6/2018 6/6/2018 3.00 PROD1 DRILL JAR T Cont. to jar &straight pull on pipe 11,870.0 11,870.0 11:00 14:00 6/6/2018 6/6/2018 1.50 PROD1 DRILL OTHR T RID &bull head 9.2 ppg OBM down 11,870.0 11,870.0 14:00 15:30 drill string w1.5 bpm @ 3000 psi. Pumped 4 bbls, then formation packed off. Attempt to pump again with no success. Bleed of psi & RID circulating equipment. Page 20147 ReportPrinted: 7/1612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stare Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 6/6/2018 6/6/2018 0.50 PROD1 DRILL ELNE T M/U FOSV & E -Line valves. Hang 11,870.0 11,870.0 15:30 16:00 sheave on top drive. 6/6/2018 6/6/2018 1.50 PROD1 DRILL WAIT T Wait on E -line crew to mobilize to rig. 11,870.0 11,870.0 16:00 17:30 Work on MP -2's & general house keeping. 6/6/2018 6/6/2018 2.00 PROD1 DRILL ELNE T Test E -line & tractor assy P/U E -Line 11,870.0 11,870.0 17:30 19:30 assy & M/U lubricator. Test to 3200 psi (good). M/U perf guns to tractor assy. (12.5" from bottom of guns to CCL) 6/6/2018 6/6/2018 3.50 PRODi DRILL ELNE T RIH w/2" pert gun tractor assy to & 11,870.0 11,870.0 19:30 23:00 correlate to 10' pup jt & HW DP. Space out top of perfs 11,524.5' / bottom of perfs 11,527.5'. Fire shot. Monitor pressure on back side with no change. POOH w/E-line 100'to 11,427'. Break circ with .5 bpm / 2000 psi. Pump 4 bbls w/good returns. Bleed off pressure on DP to 360 psi. Pressure stabilize on DP @ 780 psi. & 60 psi on back side. 6/6/2018 6/7/2018 1.00 PROD1 DRILL ELNE T POOH w/E-line f/11,427'to 5,700'. DP 11,870.0 11,870.0 23:00 00:00 pressure decrease to 40 psi & 90 psi on back side. 6/7/2018 6/7/2018 2.75 PRODi DRILL ELNE T POOH w/E-line f/5,700'. UD guns (all 11,870.0 11,870.0 00:00 02:45 shots fired(, UD tractor assy. R/D E - Line. 6/7/2018 6/7/2018 0.50 PROD1 DRILL RURD T M/U bale extensions. Lower drill string 11,870.0 11,870.0 02:45 03:15 to floor level & M/U circ sub & cement lines. 6/7/2018 6/7/2018 1.25 PROD1 DRILL CIRC T Attempt to circ w/.5 bpm @ 2500 psi. 11,870.0 11,870.0 03:15 04:30 w/300 psi on chokes. Increase to 1 bpm @ 2700 psi. Hole trying to pack off and chokes closing. Drop flow rate back to .5 bpm @ 2500 psi & remove back pressure & fully open chokes. Pumped total of 37.8 bbls w/23 bbls lost to formation. Hole packed off & started injecting into formation. 6/7/2018 6/7/2018 1.25 PROD1 DRILL OWFF T Shut down pumps & monitor well for 11,870.0 11,870.0 04:30 0545 flow. Pressure build to 800 psi on DP. Bleed off to 200 psi & shut back in & monitor for psi build up. Pressure build up to 600 psi. Repeated process until well was static. Only gained <1 bbl of fluid while letting formation relax. 6/7/2018 6/7/2018 2.50 PROD1 DRILL JAR T R/D circ lines & M/U single jt. 11,870.0 11,870.0 0545 08:15 Comence working pipe to determine if there is still movement at Jars. No success. L/D single jt. 6/7/2018 6/7/2018 2.50 PROD1 DRILL ELNE T R/U E -Line. Test E -line & tractor assy 11,870.0 11,870.0 08:15 10:45 P/U E -Line assy & M/U lubricator. Test to 3200 psi (good). M/U 2" part guns to tractor assy. (12.5" from bottom of guns to CCL) 6/7/2018 6/7/2018 3.75 PROD1 DRILL ELNE T RIH w/2" pert gun tractor assy to& 11,870.0 11,870.0 1045 14:30 correlate to DP. Space out top of perfs 11,346.74'/ bottom of parts 11,349.74'. Fire shot. Monitor pressure on back side with no change. POOH w/E-line 100'to 11,249'. Break circ with .9 bpm / 250 psi. Good returns & good communication with back side. 617/2018 6/7/2018 2.00 PROD1 DRILL ELNE T POOH & R/D E -Line. 11,870.0 11,870.0 1430 16:30 Page 21147 ReportPrinted: 7/16/2018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Cede Ac gCode Time P -T -X Operation Me) EM Depth(ft)(8) 6/7/2018 6/7/2018 3.50 PROD1 DRILL CIRC T R/U circ sub & cement lines. Break 11,870.0 11,870.0 16:30 20:00 circ & stage flow rate up to 6 bpm @ 2120 psi, Circ & cond mud to 9.2+ ppg In/Out. No losses to formation. 1730 units max gas on B/U. 6/7/2018 617/2018 1.00 FROM DRILL ELNE T Pull string in tension w/250 K. R/U E- 11,870.0 11,870.0 20:00 21:00 Line. M/U RCT easy. 6/7/2018 6!7/2018 2.00 PROD? DRILL ELNE T RIH w/RCT easy 11,400'. Started 11,870.0 11,870.0 21:00 23:00 pumping down @ 7,000' w/1 - 2.5 bpm /400 - 650 psi. 6/7/2018 6/812018 1.00 FROM DRILL ELNE T Correlating RCT assy w/pert gun run 11,870.0 11,870.0 23:00 00:00 #2. 6/8/2018 6/8/2018 0.25 FROM DRILL ELNE T Correlating RCT assy w/pert gun run 11,870.0 11,870.0 00:00 00:15 #2. RCT cut @ 11,351'. No indication of cut @ surface. 6/8/2018 6/8/2018 3.00 FROM DRILL ELNE T POOH & RID E -Line. Inspected RCT 11,870.0 11,870.0 00:15 03:15 & all indicators showed RCT functioned properly. 6/8/2018 61812018 2.50 FROM DRILL JAR T Attempt to work pipe free. Straight 11,870.0 11,870.0 03:15 05:45 pulling to 400K. Applying 22 k max trq & working string to 250K Alternate between the two. No success. Decision made to run severing tool. 6/8/2018 6/8/2018 1.25 FROM DRILL ELNE T R/U E -line & 1.75" OD severing tool. 11,870.0 11,870.0 05:45 07:00 (Radio Silence) 6/8/2018 6/8/2018 2.75 FROM DRILL ELNE T RIH w/severing tool & correlate to tool 11,870.0 11,342.0 07:00 09:45 jt @ 11,342'. No indication of sever on surface. 618/2018 6/8/2018 2.25 PRODt DRILL ELNE T POOH & R/D E -line. Inspected 11,870.0 11,342.0 09:45 12:00 severing tool & all indicators showed tool functioned propedy. 618/2018 6/8/2018 2.50 FROM DRILL JAR T Attempt to work pipe tree. Straight 11,342.0 11,342.0 12:00 14:30 pulling to 400K. Applying 22 k max trq & working string to 250K Alternate between the two. Break circ w/2.5 bpm @ 520 psi. Pipe broke free w/straight pull of 410 K. (Officially left BHA #6 in hole @ 14:30 Hrs. Bottom of BHA 11,870'. top offish @ 11,342') 61812018 6/8/2018 1.25 FROM DRILL JAR T Attempt to work pipe out of hole w/2.5 11,342.0 11,298.0 14:30 15:45 bpm @ 520 psi f/11,342'to 11,298'. Hole packed off & not able to circulate & pipe stuck. Attempt to work pipe free with no success. Pipe stuck @ 11,298' 6/8/2018 6/8/2018 1.00 PROD1 DRILL WAIT T Wait on orders & new plan forward 11,298.0 11,298.0 15:45 16:45 from town. Service rig, house keeping, & MP -2's 6/8/2018 6/8/2018 2.00 PRODi DRILL ELNE T P/U 15' DP pup & pull drill string in 11,298.0 11,298.0 16:45 18:45 tension & set slips. Clean & dear floor on non-essential E -Line tools & equipment. R/U E -Line. 6/8/2018 618/2018 3.75 PROM DRILL ELNE T Waft on E -Line & Well Tech to mobilize 11,298.0 11,298.0 18:45 22:30 tools to rig. Configure & test tool string on ground. SIMOPS - Service rig, house keeping, & MP -2's 6/8/2018 618/2018 1.00 PROM DRILL ELNE T Finish R/U E -Line. M/U E -Line tractor 11,298.0 11,298.0 22:30 23:30 assy to 9' 2" 52 shot perf gun assy. 6/8/2018 6/9/2018 0.50 PROD? DRILL ELNE T RIH w/2" perf gun assy to 3600' 11,298.0 11,298.0 23:30 00:00 6/9/2018 6/9/2018 2.75 PROD1 DRILL ELNE T RIH w/2" pert gun assy to 11,285'. 11,298.0 11,298.0 00:00 02:45 Correlate & shoot perfs. Top of perfs 11,276'/ bottom of perfs 11,285'. Pull guns up hole 100'& break circ w/.5 bpm @ 230 psi. Page 22/47 Report Printed: 7/16/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan oepM Stan Time End Time our (hri Phase Op Code AcdWy Code Time P-T-X Operabon (ftKB) End Depth (fIKB) 6/9/2018 6/9/2018 2.50 FROM DRILL ELNE T POOH w/E-Line while pumping .5 bpm 11,298.0 11,298.0 02:45 06:15 @ 230 psi. No losses. R/D E-Line & set to side. 6/912018 6/9/2018 5.50 FROM DRILL CIRC T M/U single It. Break circ & stage flow 11,298.0 11,298.0 05:15 10:45 rate up to 8 bpm / 2900 psi. 9.2+ ppg In/Out. 6/9/2018 6/9/2018 5.25 PROD1 DRILL JAR T Attempt to frre stuck pipe with no 11,298.0 11,298.0 10:45 16:00 success. Straight pull to 445 K max. Work torque down w/22 k tt/Ibs max trq. Alternating betwen the two. Pumping 2 - bpm with full returns. 6/9/2018 6/10/2018 8.00 PROD1 DRILL ELNE T Decision made to string shot back off. 11,298.0 11,298.0 16:00 00:00 M/U XO & TIW valve. R/U E-Line & top drive wire line entry guide. R/U sheaves & align E-Line cable. M/U E- Line & string shot easy & configure & test tools. SIMOPS - Work on MP2's & general housekeeping. 6/10/2018 6/10/2018 2.00 PROM DRILL ELNE T M/U E-Line & string shot easy & 11,298.0 11,298.0 00:00 02:00 configure & test tools. Bring string shot assy to rig floor & M/U to slump thru single jt DP. RIH to 300'& confirm tools working correctly. 6/10/2018 6/1012018 1.25 PROD1 DRILL ELNE T RIH w/E-Line f/300'to 3000'. Lost 11,298.0 11,298.0 02:00 03:15 communication w/CCL. Trouble shoot w/no success. 6/10/2018 6/10/2018 2.25 PRODt DRILL ELNE T POOH w/E-line. Inspect tools & re- 11,298.0 11,298.0 03:15 05:30 configure & test tools (good). (Replaced PLC & repair TTG) 6/10/2018 6/10/2018 4.50 PROD1 DRILL ELNE T RIH w/E-Line easy to 11,234' (Started 11,298.0 11,298.0 05:30 10:00 pumping down tool w/.5 - 3bpm f/7000') 6/10/2018 6/10/2018 2.75 PROD1 DRILL ELNE T Correlate string shot to box of It #8 @ 11,298.0 11,234.0 10:00 12:45 11,234'. Coordinate tugger operators & E-line for working torque down to back off point. Apply 11 k f 1lbs left hand torque (13 wraps total) & work string w/205 K up wt & 75 K dwn wt. Apply 13 k ft/lbs left hand torque (18.5 wraps total) & work string w/205 K up M & 75 K dwn wt. Correlate string shot @ 11,234' while pumping 3 bpm/730 psi. Fire 460 grain string shot & observe 1/4 left hand turn when shot fired. Initial string wt 162 K @ 12.6 Minis trapped torque. String wt after shot 154 K @ 8.7 ft/lbs trapped torque. 6/10/2018 6/10/2018 1.00 FROM DRILL JAR T POOH w/E-Line to 8,000'Apply 13 k 11,234.0 11,234.0 12:45 13:45 tt/Ibs trq left hand torque, work string 200 k up & 75 k down & observe torque decrease. Bring drill string back to neutral wt & apply 5 k ft/lbs trq left hand torque & observe drill string back off & free. 6/1012018 6/10/2018 1.50 FROM PLUG ELNE T Cont. to POOH w/E-Line 11,234.0 11,234.0 13:45 15:15 6/10/2018 6/10/2018 2.00 FROM PLUG ELNE T RIO E-Line. Remove sheaves, grease 11,234.0 11,234.0 15:15 17:15 1 1 1 1 1 1 head, & wire line entry guide. 6/10/2018 6/10/2018 0.75 FROM PLUG PMPO T Pump OOH w/4 bpm 1830 psi 11,234.0 10,997.0 17:15 18:00 1 I f/11,234' to 10,997'. PU wt 190 K / SO wt 155 K 6/10/2018 6/10/2018 1.25 PROD1 PLUG CIRC T Circ & cond mud w/8 bpm / 2950 psi. 10,997.0 10,997.0 18:00 19:15 1 I SIMOPS - Clean & clear floor. LID single jt & pup jt from mouse hole. Page 23147 Report Printed: 711612018 Operations Summary (with Timelog Depths) AN x " MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth StortTme I End Time our(hr) Phase Op Code Activity Code_ Time P-T-X Operabon (ftKB) End Dept (ftKB) 6/10/2018 6/10/2018 1.00 PROD1 PLUG CIRC T Mud out of balance. R/U head pin & 10,997.0 10,997.0 19:15 2015 cement hose. Circ & cond mud w/5 bpm / 1400 psi. Mud wt 9.2 In/Out. SIMOPS - Shuffle 5 stands 15.7 # DP f/DS to ODS. Check torque on every connection & SLM 6/10/2018 6/10/2018 0.75 PROD1 PLUG OWFF T OWFF. Slight oose & slowing down, 10,997.0 10,997.0 20:15 21:00 then static. SIMOPS - B/D cement line. R/D head pin & cement hose. 6/10/2018 6/10/2018 0.50 PROD1 PLUG MPDA T PJSM, Remove RCD bearing & install 10,997.0 10,997.0 21:00 21:30 trip mupple. 6/10/2018 6/10/2018 0.50 PROD1 PLUG CIRC T Pump 30 bbls 10.5 ppg dry. Line up on 10,997.0 10,997.0 21:30 22:00 trip tank to POOH 6/10/2018 6/11/2018 2.00 PROD1 PLUG TRIP T POOH on elevators on TT f/10,997' to 10,997.0 9,385.0 22:00 00:00 9,385'. Check torque on every connection & SLM 6/11/2018 6/11/2018 10.25 PROD1 PLUG TRIP T POOH on elevators on TT 1/9,386to 9,395.0 0.0 00:00 10:15 surface. Check torque on every connection & SLM. Last stand #4 + 1 single jt. 6/11/2018 6/11/2018 0.50 PROD1 PLUG OWFF T F/C (static). SIMOPS - Clean & clear 0.0 0.0 10:15 10:45 1 floor. 6/11/2018 6/11/2018 0.75 PROD1 WHDBOP RURD T M/U wear ring puller & pull same. 0.0 0.0 10:45 11:30 Install 3-1/2" test jt as per FMC. Fill BOP stack, flood lines & purge system. 6/11/2018 6/11/2018 1.50 PROD1 WHDBOP BOPE T Test annular with 3-1/2" test jt 250 psi 0.0 0.0 11:30 13:00 5 min 12500 psi 10 min & not able to get a good high test. pressure bleeding off. Test upper & lower 3-1/2" X 6" VBR's 250 psi for 5 min /3500 psi for 10 min & good test. Make another un-successful attempt to test annular 6/11/2018 6/11/2018 5.00 PROD1 WHDBOP BOPE T Function annular& still not able to 0.0 0.0 13:00 18:00 test. Observe large piece of annular rubber lodged in annular cavity. Dislodge rubber & attempt to re-test w/no success. 6/11/2018 6/11/2018 2.00 PROD1 WHDBOP RGRP T Pull test jt & drain stack. Observe 0.0 0.0 1800 20:00 debris in blind ram cavity (annular element rubber). Install test plug & 3- 1/2" test jt. & close lower rams. Open blind ram door & remove debris. Tighten back ram door. Open lower rams. Remove test plug & UD test jt. 6/11/2018 6/11/2018 1.50 PROD1 WHDBOP RGRP T B/D hole fill lines. N/D MPD 0.0 0.0 20:00 21:30 equipment. Remove trip nipple, flow line & flow box. UO mouse hole. 6/11/2018 6/11/2018 2.00 PRODi WHDBOP RGRP T R/U & break annular cap. C/O 0.0 0.0 21:30 23:30 hydraulic fluid. Replace annular element. Tighten annular cap & function test (good). 6/11/2018 6/12/2018 0.50 PROD1 WHDBOP RGRP T Install MPD clamp 0.0 0.0 2330 0000 6/12/2018 6/12/2018 3.00 PROD1 WHDBOP RGRP T N/U MPD equipment, flow box, hole fill 0.0 0.0 00:00 0300 & bleeder lines, etc. Install trip nipple & mouse hole. 6/12/2018 6112/2018 0.50 PROD1 WHDBOP RGRP T P/U 4" test jt & set test plug. Fill stack 0.0 0.0 0300 03:30 with H2O, flood lines & purge system. 6/12/2018 6/12/2018 2.00 PROD1 WHDBOP RGRP T Test annular & blind ram doors w/4" 0.0 0.0 03:30 05:30 test jt 250 psi for 5 min / 3500 psi for 10 min. Test annular w/3.5" test jt 250 psi for 5 min / 2500 psi for 10 min. Page 24147 ReportPrinted: 7116/2018 B Operations Summary (with Timelog Depths) �r7•rt MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur (hi Phase Op Code Activity Code Time P -T -X Operation ptKB) End Depth(ftKB) 6/12/2018 6/12/2018 0.50 PROD1 WHDBOP RURD T R/D testing equipment. L/D test plug & 0.0 0.0 05:30 06:00 test it. Install wear ring as per FMC. 6/12/2018 6/12/2018 1.25 PROD1 PLUG RURD T R/U to run tubing. R/U power tongs, 3- 0.0 0.0 06:00 07:15 1/2" slips & elevators. 6/12/2018 6/12/2018 1.75 PROD1 PLUG PUTB T RIH 3-1/2" cement stinger assy to 0.0 1,056.0 07:15 09:00 1,056' (18' mule shoe stinger, 33 its tubing, & XO) 6/12/2018 6112/2018 7.00 PROD1 PLUG TRIP T C/O over to 4" handle equipment. RIH 1,056.0 11,065.0 0900 16:00 w/4" DP f/1,056 to 11,065' (Culled out 12 its of 14# DR found bad box & pin stand #70 in between its 1 & 2 of original tally) 6/12/2018 6112/2018 0.50 PROW PLUG WASH T Wash Cowin @ 3 bpm / 670 psi -& tag 11,065.0 11,233.0 1600 16:30 TOF @ 11,233' 6/12/2018 6/12/2018 0.75 PROD1 PLUG CIRC T Break circ &stage flow rate up to 6 11,233.0 11,233.0 1630 17:15 bpm / 2000 psi 6/12/2018 6/12/2018 1.75 PROM PLUG DISP T Pump 3 different spacers (high vis, 11,233.0 11,233.0 1715 19:00 deep clean, high vis) n& displace well to 9.2 ppg vis brine w/3 - 6 bpm / 670 - 2000 psi 6/12/2018 6/12/2018 0.75 PROM PLUG CIRC T Circ an additional B/U to even out 11,233.0 11,233.0 1900 19:45 brine. 6 bpm / 670 psi 6/12/2018 6/12/2018 0.50 PROM PLUG RURD T L/D top single it. Mi8' pup it, TIW, 11,233.0 11,233.0 19:45 20:15 head pin & cement hose. 6/12/2018 6/12/2018 1.50 PROD? PLUG CIRC T Break circ through cement line 6 bpm I 11,233.0 11,233.0 20:15 21:45 800 psi. PJSM for cementing. SIMOPS - Build black water pill. 6/12/2018 6/12/2018 0.75 PROM PLUG CMNT T SLB pump 5.2 bbis H2O CPT lines to 11,233.0 11,233.0 21:45 22:30 3500 psi. Pump 24.4 bbls 12.75 ppg push @ 2.5 bpm 1250 psi, 22.9 Irmud bbls 16.5 ppg 1.06 H3/sx yield class G cement 4 bpm / 760 psi, 1 zt j bbls12.75 ppg mud push @ 2.2.2 bpm / � 160 psi, & 1.4 bbls H2O to clear lines. Rig pump 93 bbls 9.2 ppg brine, Initial 6 bpm / 790 psi & final 3 bpm / 400 6/12/2018 6/12/2018 0.25 FIR PLUG RURD T R/D cement hose, head pin & TIW. 11,233.0 11,233.0 22:30 22:45 1 L/D 8' pup it. 6/12/2018 6/13/2018 1.25 PROD1 PLUG TRIP T POOH 600 ft/hr first 3 stands & 1000 11,233.0 10,589.0 2245 00:00 ft/hr remaining f111,233'to 10,589' CIP @ 00:00 Hrs 6/13/18 6/13/2018 6/13/2018 2.00 PROD1 PLUG CIRC T Circ & cond mud with 6 bpm / 860 psi. 10,589.0 10,589.0 0000 02:00 Saw mud push & trace of cement on B/U. Circ & cond mud for an additional B/U w/8 bpm 1930 psi. Dumped total of 73 bbls contaminated brine. Obtain SPR's. 6/13/2018 6/13/2018 0.25 PROM PLUG OWFF T F/C (slight moze then static) 10,589.0 10,589.0 0200 02:15 6/13/2018 6/13/2018 7.75 PROD? PLUG TRIP T POOH on elevators f/10,589'to 1,056'. 10,589.0 1,056.0 02:15 10:00 SLM & alternate connection breaks 6/13/2018 6/13/2018 0.25 PROM PLUG RURD T R/U to L/D tubing. M/U TIW & XO 1,056.0 1,056.0 10:00 10:15 6/13/2018 6/13/2018 2.75 PROD1 PLUG PULD T POOH & L/D cement stinger assy 1,056.0 0.0 10:15 13:00 f/1,056'. (XO, 33 its tubing & stinger) 6/13/2016 6/13/2018 2.25 PROD1 WHDBOP BOPE T Test rig gas alarms with witness of 0.0 0.0 1300 15:15 AOGCC rep Guy Cook. SIMOPS - R/D tubing equipment. Clean & clear floor. P/U test jt & pull wear ring. Set test plug. R/U to test BOPE. Fillj stack with H2O. Flood & purge lines. Page 25147 ReportPrinted: 711 612 01 8 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depm start Time End Time Dur (hr) Pheae Op code Activity Code Tme P -T -X Opemoi, (RKB) End Depin (ftKB) 6/13/2018 6/13/2018 6.75 PROD1 WHDBOP BOPE T Test BOPE 250/3500 for 5/10 min's 0.0 0.0 15:15 22:00 w/4" & 4-1/2" test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, lower 3-1/2" X 6" VBR's & blind rams, 4" DBrt/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3125 psi, final 1400 psi, 1st 200 psi recharge = 28 sec's, full recharge = 160 second. 4 bottles @ 2200 psi. PVT alarms and flow indicated tested. Draw dowm on maunual & super choke. AOGCC Gut Cook witness & BUM Mutasim Elganzoory waived witness via email. 6/13/2018 6113/2018 0.75 PROD1 WHDBOP RURD T RID testing equipment. Pull test plug. 0.0 0.0 22:00 22:45 Drain slack. BID choke & lines. Set 6.1875" ID marring. 6/13/2018 6/13/2018 0.75 PROD1 PLUG BHAH T Bring to dg floor BHA tools & 0.0 0.0 22:45 23:30 equipment. 6/13/2018 6/14/2018 0.50 PROD1 PLUG SHAH T PJSM. M/U 6" clean out BHA as per 0.0 39.0 23:30 00:00 Baker reps to 39' 6/14/2018 6/14/2018 3.25 PROD1 PLUG -ETH-AH T M/U 6" clean out BHA as per Baker 39.0 218.0 00:00 03:15 reps f/39' to 218' 6/14/2018 6/14/2018 1.00 PROD1 PLUG TRIP T RIH f/218'to 2,183' 218.0 2,183.0 03:15 04:15 6/14/2018 6/14/2018 0.25 PROD1 PLUG DHEO T Shallow hole test MWD w/200 gpm/ 2,183.0 2,183.0 04:15 04:30 430 psi (good) 6/14/2018 6/14/2018 4.00 PROD1 PLUG TRIP T RIH f/2,183'to 8,575' PU wt 185 K / 2,183.0 8,575.0 04:30 08:30 SO wt 145 K 6/14/2018 6114/2018 0.75 PROD1 PLUG DLOG T Break circ w/ 220 gpm / 940 psi & log 8,575.0 8,670.0 08:30 09:15 RA tag 8584'. Cont. to was down BHA thru quick conned. Observe 6K bobble when mill @ quick connect. 6/1412018 6/14/2018 1.25 PRODI PLUG TRIP T RIH f18,670' to 10,480' PU wt 202 K / 8,670.0 10,480.0 09:15 10:30 SO wt 150 K 6/14/2018 6/14/2018 0.75 PROD1 PLUG REAM T W&R f/10,480'to TOC @ 10,627' 10,480.0 10,627.0 10:30 11:15 w/220 gpm 11080 psi, 6/14/2018 6/14/2018 4.50 PROD1 PLUG DRLG T Drill cement fl10,627'to 11,127.5' 10,627.0 17,127.5 11:15 15:45 w/250 gpm, 1170 psi, PU wt 205 K, SO wt 145 K, ROT wt 170 K, 60 rpm, 7-10 ktrq 6/14/2018 6/14/2018 0.25 PRODI PLUG CIRC T Ta TOC 11 127. ' B 11,127.5 11,127.5 w/1.5 bpm 1160 psi with witness of 15:45 16:00 AOGCC rep Guy Cook 6/14/2018 6/14/2018 1.50 PRODI PLUG CIRC T Circ & cond brine. Pump high vis 11,127.5 11,127.5 16:00 17:30 sweep & circ clean w/250 gpm 11100 psi, 60 rpm / 7 k tM. 6/14/2018 6/1412018 0.25 PRODI PLUG OWFF T F/C- slight ooze &slowing down. 11,127.5 11,127.5 17:30 17:45 1 Suspect brine is out of balance. 6114/2018 6/14/2018 1.25 PRODI PLUG TRIP T POOH on elevators 1/11,127.6to 11,127.5 10,480.0 17:45 19:00 10,480'. Appear to be dragging junk out of hole and having improper hole fill. 6/14/2018 6/14/2018 1.75 PROD1 PLUG CIRC T Pump high vis sweep & circ hole clean 10,480.0 10,480.0 19:00 20:45 w/240 gpm 11170 psi, 50 rpm /7 k trq. 6/14/2018 6/14/2018 0.75 PROD? PLUG TRIP T F/C - (static). POOH on elevators 10,480.0 10,003.0 20:45 21:30 1 f/10,480' to 10,003'. Hole fill correct. 6/14/2018 6/14/2018 0.50 PR PLUG CIRC T Pump dry job. B/D top drive 10,003.0 10,003.0 21:30 22:00 6/1412018 6/14/2018 1.50 PRODI PLUG TRIP T POOH on elevators f/10,003'to 8,575'. 10,003.0 6,575.0 22:00 23:30 PU wt 188 K I SO wt 145 K Page 26147 ReportPrinted: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth startTMa I EM Time Phase rip Code Activity Dotle Time P -T -X Operation MKS) End Depth (ftKB) /14/2018 6/15/2018 FROM PLUG SLPC T PJSM. Slip & cut 45'drill line 8,575.0 8,575.0 23:30 00:006/15/2016 6/15/2018 rOur(hr) PROM PLUG SLPC T Slip & cut 45'drill line 8,575.0 8,575.0 00:00 00:306/15/2018 6/1512018 PRODI PLUG SVRG T Service Rig, top drive, draworks, 8,5750 8,575.0 00:30 01:00 perform MP -2's 6/15/2018 6/15/2018 PROD1 PLUG TRIP T POOH on elevators 1/8,575' to 281' 8,575.0 281.0 01:00 06:00 6115/2018 6/15/2018 0.25 PROD1 PLUG OWFF T F/C (static). SIMOPS - PJSM on BHA 281.0 281.0 06:00 06:15 6/15/2018 6/15/2018 1.50 FROM PLUG BHAH T L/D clean out BHA as per Baker rep. 281.0 0.0 06:15 07:45 j 6/15/2018 6/1512018 0.50 FROM PLUG BHAH T Clean & Gear BHA tools from rig floor. 0.0 0.0 07:45 08:15 Bring whipstock BHA components to rig floor. 6115/2018 6/15/2018 3.25 PROM PLUG BHAH T M/U whipstock BHA as per Baker rep. 0.0 265.0 08:15 11:30 6/15/2018 6/15/2018 5.75 FROM PLUG TRIP T RIH whi stock BHA f126 ' 265.0 8,650.0 11:30 17:15 6/15/2018 6/15/2018 0.75 FROM PLUG DLOG T Break circ w/ 250 gpm 11370 psi & log 8,650.0 8,748.0 17:15 18:00 RA tag 8586' no rotation. Cont. to was down BHA thru quick connect. PU wt 175k/SO wt 140k 6/15/2018 6/15/2018 1.00 FROM PLUG TRIP T RIH whipstock BHA f/8,748'to 10,453'. 8,748.0 10,453.0 18:00 19:00 6/15/2018 6/15/2018 0.25 PROM PLUG TRIP T Take 8 K WOB down @ 10,453'. P/U 10,453.0 10,407.0 19:00 19:15 & observe break over @ 15 K max over pull. Drop back down & lake 8 K WOB down @ 10,439'. POOH to 10,407' & observe break over @ 15 K max over pull. Decision made to circ hole clean. Free P/U wt 200 K / Free SO wt 150 k 6115/2018 6115/2018 1.25 PROD1 PLUG CIRC T Circ 2X B/U w/250 gpm / 1430 psi. 10,407.0 10,407.0 19:15 20:30 Saw slight amount of cement cuttings after 1 st B/U. 6/15/2018 6/15/2018 0.25 FROM PLUG TRIP T After circulating free P/U wt 200 K / 10,407.0 10,439.0 20:30 20:45 Free SO wt 157 k. Attempt to RIH f/10,407'& take 8 K WOB @ 10,439'. Decision to POOH 6/15/2018 6/15/2018 1.00 PROD? PLUG TRIP T POOH w/whipstock assy f/10,439' to 10,439.0 9,892.0 20:45 21:45 9,892. 611512018 6115/2018 0.50 FROM PLUG CIRC T FIC (static). Pump 38 bbl dry job & 9,892.0 9,892.0 21:45 22:15 ISIDtopdrive. 6/15/2018 6/15/2018 1.00 PROD1 PLUG TRIP T POOH w/whipstock easy f/9,892 to 9,892.0 9,416.0 22:15 23:15 9,416'. (15 K overpulls @ 9,816', 9,649', 9,608', 9,570', & 9,443', appears we are dragging debris out of hole & hanging up). PU wt 192 K / SO wt 155K 6/15/2018 6116/2018 0.75 PROD1 PLUG CIRC T Circ & cond w/250 gpm / 1430 psi. 9,416.0 9,416.0 23:15 00:00 6/16/2018 6116/2016 0.50 FROM PLUG CIRC T Cont. circ & cond w/250 gpm / 1370 9,416.0 9,416.0 00:00 00:30 psi. 6/16/2018 6/16/2018 1.25 FROM PLUG TRIP T POOH w/whipstock easy f/9,416'to 9,416.0 8,727.0 00:30 01:45 8,727'. (15 - 20 K overpulls, we are dragging debris out of hole & hanging up). PU wt 185 K / SO wt 148 K. 6/16/2018 6/16/2018 0.50 PROD? PLUG PMPO T Having difficulty pulling whipstock 8,727.0 8,653.0 01:45 02:15 assay thru quick conned. Not able to work down. Pump assy out of hole w/250 gpm / 1330 psi. 20 K max over pull. Page 27/47 Report Printed: 71176120118 Operations Summary (with Timelog Depths) 1 AE -4 1 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sad Depth Start Time I End Time our (hr) Phase Op Code Aravi(y Code Time P -T -X Operation (RKB) End Depth (BKB) 6/16/2018 1611612018 7.25 PRODI PLUG TRIP T Cont. to POOH f/8653'to 356'. No 8,553.0 356.0 02:15 09:30 more overpulls once tru quick connect. 6/16/2018 6/16/2018 0.25 PRODI PLUG OWFF T FIC (static) PJSM on BHA 356.0 356.0 09:30 09:45 6/16/2018 6116/2018 2.00 PROD1 PLUG BHAH T UD whipstock assy f/356' as per 356.0 0.0 09:45 11:45 Baker rep. Large metal debris on lower string magnet, window mill bolt. & window hook slot. No signs of stress on whipstock shear bolt or anchor bolts. 6/16/2018 6/16/2018 1.00 PROD1 PLUG BHAH T Clean & clear BHA tools & equip from 0.0 0.0 11:45 12:45 Floor. Bring clean out BHA components to floor. 6/16/2018 6/16/2018 0.75 PROD1 PLUG OTHR T Perform trial run for wireline entry 0.0 0.0 12:45 13:30 guide on top drive. 6/16/2018 6/16/2018 1.00 PROD1 PLUG BHAH T WU clean out BHA as per Baker rep 0.0 67.0 13:30 14:30 to 67'. Waiting on junk basket to be flow over from Deadhorse. 6/16/2018 6/16/2018 0.50 PROD1 PLUG SVRG T Service rig, draw works & iron 67.0 67.0 14:30 15:00 roughneck. 6/1612018 6/1612018 1.75 PROD1 PLUG WAIT T Clean wind walls, housekeeping, & 67.0 67.0 15:00 16:45 MP -2's. Waiting on junk basket to be flow over from Deadhorse. 6/16/2018 6116/2018 1.00 PROD1 PLUG BHAH T Finish M/U clean out BHA as per 67.0 102.0 16:45 17:45 Baker rep f/67'to 102' 6/16/2018 6116/2018 3.75 PROD1 PLUG TRIP T RIH f/102'to 8,606' Fill pipe every20 102.0 8,606.0 17:45 21:30 stands. 6/16/2018 6116/2018 0.75 PRODI PLUG CIRC T Break circ & stage flow rate up to 690 8,606.0 8,606.0 21:30 22:15 gpm / 3900 psi 6/16/2018 6116/2018 1.00 PRODI PLUG WASH T Wash thru TOL & quick connect w/690 8,606.0 8,893.0 22:15 23:15 gpm / 3950 psi, f/8,606'to 8,893'. No issues or tight spots running thru quick connect. 6/16/2018 6/17/2018 0.75 PROD1 PLUG REAM T W&R w/690 gpm / 3950 psi, 30 rpm / 8,893.0 9,229.0 23:15 00:00 5 k trq f/8,893'to 9,229. PU wt 160 k, SO wt 127 k, ROT wt 144 k 6/17/2018 6/17/2018 6.75 PROD1 PLUG REAM T W&R w/690 - 600 gpm 14000 psi, 30 9,229.0 11,086.0 00:00 06:45 rpm / 5 - 7 k trq f/9,229'to 11,086'. PU wt 210 k, SO wt 150 k, ROT wt 160 k. Appear to be pushing debris to bottom. Pump sweep Q 10,989' 6/17/2018 6/17/2018 0.25 PRODI PLUG WASH T Wash f/11,088'& TOC @ 11,127.5' 11,088.0 11,127.5 06:45 07:00 w/80 gpm / 180 psi. Tag w/8 k WOB. Pick up & mark string 6' off of bottom for compression adjustment and stay off bottom w/ rotating 6/17/2018 611712018 1.50 PROD1 PLUG CIRC T Pump sweeps& circ casing clean 11,127.5 11,127.5 07:00 08:30 w/600 gpm / 4000 psi, 30 rpm / 7 k trq. saw some increase in cement cuttings when sweep was at surface. 6/17/2018 611712018 0.25 PROD1 PLUG OWFF T F/C-slight ooze, Brine appears to be 11,127.5 11,127.5 08:30 08:45 1 aired up. 6/17/2018 6/17/2018 0.25 PRODI PLUG TRIP T POOH f/11,127.5'to 11,084' 11,127.5 11,084.0 08:45 09:00 6/17/2018 6117/2018 0.25 PROD1 PLUG OWFF T FIC -(static) 11,084.0 11,084.0 09:00 09:15 6/17/2018 6/17/2018 1.75 PROD? PLUG TRIP T POOH on elevators f/11,084'to 8,703' 11,084.0 8,703.0 09:15 11:00 w/no issues. 6/17/2018 6/17/2018 2.00 PROD1 PLUG CIRC T Pump sweep & circ casing dean & 8,703.0 8,703.0 11:00 13:00 quick conned & TOL w/625 - 300 gpm / 3200 - 1000 psi. Vary flow rates & reciprocate pipe to flush out any debris. Page 28147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time our(hn phase Op Cone Actively Code Time P -TA Operation (ftKB) End Depth(ftKB) 6/17/2018 6/17/2018 0.25 PROD1 PLUG OWFF T F/C-(static) 8,703.0 8,703.0 13:00 13:15 6/17/2018 6117/2018 0.75 PROW PLUG TRIP T POOH on elevators f/8,703' to 7,750' 8,703.0 7,750.0 13:15 14:00 w/no issues. 6/17/2018 6/1712018 0.25 PROD1 PLUG CIRC T Pump 37 bbl 10.0 ppg dryjob 7,750.0 7,750.0 14:00 14:15 6/17/2018 6/17/2018 3.00 PROD1 PLUG TRIP T POOH on elevators f/7,750' to 219' 7,750.0 219.0 14:15 17:15 w/no issues. 6/17/2018 6117/2018 0.25 PROD1 PLUG OWFF T F/C-(static) 219.0 219.0 17:15 17:30 6/17/2018 6/17/2018 0.75 PROD1 PLUG BHAH T LID clean out BHA as per Baker reps 219.0 65.0 17:30 18:15 f/219' to 65'. Lots of large metal debris on magnets (cement retainer pieces). Additional debris in junk baskets 6/17/2018 6/17/2018 0.25 PROD1 PLUG BHAH T Clean & clear floor. 65.0 65.0 18:15 18:30 6/17/2018 6/17/2018 0.50 PROD1 PLUG BHAH T Finish L/D clean out BHA. 65.0 0.0 18:30 19:00 6/17/2018 6/17/2018 0.25 PROD1 PLUG BHAH T Clean & clear floor. LID clean out BHA 0.0 0.0 19:00 19:15 via beaver slide. 6/17/2018 6/17/2018 2.00 PROD1 PLUG BHAH T M/U Whipstock/milling easy as per 0.0 328.0 19:15 21:15 Baker reps to 328'. Change out anchor bolts & verify offset @ 337.75 6117/2018 6/1712018 1.00 PROD1 PLUG TRIP T RIH whipstock/milling assy f/328'to 328.0 2,230.0 21:15 22:15 2,230' 6/17/2018 611712018 0.25 PROD1 PLUG DHEQ T Shallow hole test MWD w/250 gpm / 2,230.0 2,230.0 22:15 22:30 900 psi 6/17/2018 6/1812018 1.50 PRODi PLUG TRIP T RIH whipstock/milling assy f/2,230'to 2,230.0 4,816.0 22:30 00:00 4,816'. Fill pipe every 20 stds 6/18/2018 6/18/2018 2.50 PRODi PLUG TRIP T RIH whipstock/milling assy f/4,816'to 4,816.0 8,526.0 00:00 02:30 8,526'. Fill pipe every 20 stds. No issues. 6/18/2018 6/18/2018 0.75 PROW PLUG DLOG T Wash down f,8,526' to 8,717' & log RA 8,526.0 8,717.0 02:30 03:15 tag @ 8,587' 6/18/2018 6/18/2018 1.75 PROD1 PLUG TRIP T RIH whipstock/milling assy f/8,717'to 8,717.0 11,003.0 03:15 05:00 11,003'. Fill pipe every 20 stds. No issues. 6/18/2018 6/18/2018 1.00 PROD1 PLUG WASH T Wash down f/11,003'to 11, 11 Tw/230 11,003.0 11,117.0 05:00 06:00 gpm / 1350 psi & orient whipstock 30° left. PU wt 212 k / SO wt 155 k 6118/2018 6/18/2018 0.25 PROD1 PLUG WPST T Set whi stock as DerB - 11,117.0 11,106.0 f/11,117' to 11,127.5'& set anchor 06:00 06:15 w/17 k WOB. PU to 220 k & confirm anchor set. SO w/33 k WOB & shear mill from slide. PU & observe free travel with milling assy. TOW - 11,106.2' / BOW - 11,119.5' 6/18/2018 6118/2018 0.25 PRODi PLUG WPST T P/U to 11,079'. Obtain SPR's & prep to 11,106.0 11,106.0 06:15 06:30 mill window. Wash down f/11,079' to 11,106'w/230 gpm 11350 psi, 80 Fpm /9ktrq 6/18/2018 6/18/2018 4.50 PROD1 PLUG WPST T Mill window f/11, 106'to 11, 119'w/230 11,106.0 11,119.0 0630 11:00 gpm / 2050 psi, 80 - 100 rpm / 9 - 10 k trq. 6/18/2018 6/1812018 3.25 PROD1 PLUG WPST T Cont. to polish off window & drill 20' 11,119.0 11,139.0 11:00 14:15 new hole IT gauge hole) f/11,119' to 11,139'w/220 gpm, 2050 psi, 10 - 12 k WOB, 100 rpm, 9 - 10 k lrq, PU wt 212 k, SO wt 155 k, ROT wt 175 k. 6/18/2018 6/18/2018 0.50 PROW PLUG WPST T Dress & polish off window. Work thru 11,139.0 11,139.0 1415 1445 1 with & without pumps. With & without rotation. (good). Page 29147 Repon Printed: 7/16/2018 Operations Summary (with Timelog Depths) MT6-O5 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start oepm Start Time End Time Our (hr) Phase Op Code Acli * Code Time P -T -X Operation MKS) End Oeptn (ftKB) 6/18/2018 6/18/2018 1.50 PROD? PLUG CIRC T Pump sweep & circ hole clean for FIT 11,139.0 11,075.0 14:45 16:15 w/250 gpm / 2230 psi, 50 rpm 18.5 k trq. Pump out of hole to 11,075' 6/18/2018 6/1812018 0.75 PROD1 PLUG FIT T R/U testing equipment. FIT to 12.5 11,075.0 11,075.0 16:15 17:00 ppg. RID testing equipment. 6/18/2018 6/1812018 2.75 PROD1 DRILL DISP T PJSM. Displace milling fluid to new 11,075.0 11,075.0 17:00 19:45 9.2 ppg vis Brine w/250 gpm 12300 - 1320 psi, 50 rpm / 8.5 k trq. 6/18/2018 6/18/2018 0.25 PROD1 DRILL OWFF T FIC (static) 11,075.0 11,075.0 19:45 20:00 6/18/2018 6/19/2018 4.00 PRODt DRILL TRIP T POOH on elevators f/11,075'to 7,037' 11,075.0 7,037.0 20:00 00:00 611912018 6/19/2018 0.75 PROD1 DRILL TRIP T Pull out of hole from 7.037' MD to 7,037.0 5,836.0 00:00 00:45 5,836' MD on elevators, P/U=145k, S/0=125k. 6/19/2018 611912018 0.25 PROD1 DRILL CIRC T Pump 39 bbl slug @ 10 ppg 5,836.0 5,836.0 00:45 01:00 6/1912018 6119/2018 2.50 PROD1 DRILL TRIP T Continue POOH on elevators from 5,836.0 305.0 01:00 03:30 5,836' MD to 305' MD. 6/1912018 6/19/2018 0.25 PROD1 DRILL 01 T 01 -static. 305.0 0.0 03:30 03:45 PJSM on laying down BHA. 6119/2018 6/19/2018 0.50 PROD1 DRILL BHAH T Lay down milling assembly from 305' 0.0 0.0 03:45 04:15 MD to surface per BOT fishing rep. 6/19/2018 6119/2018 0.50 PROD1 DRILL BHAH T Clean and clear rig floor, lay down 0.0 0.0 04:15 04:45 tools and equipment via beaver slide. 6/19/2018 6119/2018 0.75 PROD1 DRILL WW -WH T Make up stack washer and string 0.0 0.0 04:45 05:30 j magnets, flush stack @ 700 gpm, 170 psi, 20 rpm 3K. 6119/2018 6/19/2018 0.25 PROD1 DRILL WWWH T Lay down stack washer and string 0.0 0.0 05:30 05:45 magnets (Functioned rams and annular) 6/19/2018 6/19/2018 2.25 PROD1 DRILL BHAH T PJSM, M/U kick-off motor (1.5°) BHA 0.0 781.0 05:45 08:00 per BOT to 781' MD. Confirm MWD / Motor TFO=317°. 6/19/2018 6119/2018 0.50 PROD1 DRILL TRIP T Run in hole with kickoff assembly from 781.0 2,207.0 08:00 08:30 781' MD to 2,207' MD. 6/19/2018 6/19/2018 0.25 PR0D1 DRILL DHEQ T Shallow test MWD @ 220 gpm, 620 2,207.0 2,207.0 08:30 08:45 psi - good. 6119/2018 6/19/2018 3.00 PROD1 DRILL TRIP T Continue RIH with KICKott BHA from 2,207.0 8,598.0 08:45 11:45 2,207' MD to 8,598' MD, filling pipe every 20 stands. P/U=195k, S/0=145k. 6/19/2018 6/1912018 0.25 PROD1 DRILL RURD T Rig up Baker BPA to down link (mode 8,598.0 8,598.0 11:45 12:00 switch). Annulus B=50 psi, Annulus C=0 psi @ 12:00 hrs 6/19/2018 6/19/2018 0.50 PRODi DRILL DLOG T Wash down from 8,598' MD to 8,637' 8,598.0 8,637.0 12:00 12:30 MD logging RA tag @ 230 gpm, 990 psi. Pick up tag @ 8,585' MD (8,627' bit depth). 6119/2018 6119/2018 1.50 PROD1 DRILL TRIP T Continue RIH from 8,637' MD to 8,637.0 10,790.0 12:30 14:00 10,790' MD. 6/19/2018 6119/2018 1.00 PROD1 DRILL SLPC T PJSM, Cut and slip 75' drilling line. 10,790.0 10,790.0 14:00 15:00 6/19/2018 6/19/2018 0.50 PROD1 DRILL SVRG T Service top drive, draworks. Calibrate 10,790.0 10,790.0 15:00 15:30 block height. 6/19/2018 6/19/2018 0.75 PRODt DRILL WASH T Wash down from 10,790' MD to 10,790.0 11,139.0 15:30 16:15 10,980' MD, RIH without pump across whipstock slide to 11,119, continue wash down to bottom 11,139' MD. 6/19/2018 6119/2018 2.50 PROD1 DRILL DDRL T Directional drill from 11,139' MD to 11,139.0 11,313.0 16:15 18:45 11,313' MD, 8,016' TVD, 85' inc. Page 30147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stall Time End Time our (hr) Pheae Op CodeAmvity Coda True P-T-X Opemtlon ^B) End Depth (11x13) 6/19/2018 6/19/2018 0.75 PRODt DRILL CIRC T Circulate @ 170-200 gpm, 670-950 11,313.0 11,313.0 18:45 19:30 psi, CBU X 1 while discussing plan forward. Decide to pull out of hole for Rotary steerable drilling assembly. 6/19/2018 6/19/2018 0.75 PRODt DRILL PMPO T Pull out of hole with pump @ 200 11,313.0 11,076.0 19:30 20:15 gpm, 950-880 psi from 11,313' MD to 11,171' MD. Shut down pump and pull bit across whipstock ramp to 11,076' MD, good. 6/19/2018 6/19/2018 1.50 PRODi DRILL CIRC T Pump 35 bbl HV brine sweep, pump 11,076.0 11,076.0 20:15 21:45 around and out @ 250 gpm, 1200- 1280 psi, bottoms up cleaned up good, sweep brought back little returns 6/19/2018 6/1912018 0.50 PRODt DRILL OWFF T Flow check well, static in 20 minutes, 11,076.0 11,076.0 21:45 22:15 slight drop after 30. 6/19/2018 6/2012018 1.75 PROD1 DRILL TRIP T Pull out of hole on elevators from 11,076.0 9,170.0 22:15 00:00 11,076' MD to 9,170' MD, proper hole fill. Annulus B=70 psi, Annulus C=0 psi @ 23:00 hrs 6/20/2018 6/2012018 4.00 PROD1 DRILL TRIP T Continue POOH on trip tank from 9,170.0 781.0 00:00 04:00 9,170' MD to 781' MD, observe proper hole fill. 6/20/2018 6/2012018 0.25 PROD1 DRILL OWFF T Flow check well static at HWDP. 781.0 781.0 04:00 04:15 6/20/2018 6/2012018 1.75 PROD1 DRILL BHAH T Lay down BHA per BOT reps, rack 781.0 0.0 04:15 06:00 back HWDP and Jars, 15.7# DP. String magnets @ 40% capacity. Check TFO on motor /MWD, observe 65° L discrepency. 612012018 6120/2018 0.75 PROD1 DRILL BHAH T Clean and clear rig floor, lay down 0.0 0.0 06:00 06:45 tools and equipment. Clean rig floor. 6120/2018 6/20/2018 0.50 PROD1 DRILL SHAH T PJSM, M/U BHA#13 to 67' per Baker 0.0 67.0 06:45 07:15 reps. 6120/2018 6120/2018 0.50 PROD1 DRILL BHAH T Plug in MWD and upload. 67.0 67.0 07:15 07:45 SIMOPS- M/U 2 NMFC, Float, Filter, Float, NM slab with tuggers and 90' mousehole. Prep source box. 6120/2018 612012018 0.25 PROD1 DRILL BHAH T Continue M/U BHA #13 to 144' MD. 67.0 144.0 07:45 08:00 6120/2018 6/20/2018 0.25 PROD1 DRILL BHAH T Baker MWD load sources in tool. 144.0 144.0 08:00 08:15 6/2012018 6/2012018 0.25 PROD1 DRILL BHAH T Continue making up BHA#13 from 144.0 332.0 08:15 08:30 144' MD to 332' MD. P/U=97k, S/0=97k. 6/20/2018 6/20/2018 0.75 PROD1 DRILL TRIP T RIH from 332' MD to 2,234' MD from 332.0 2,234.0 08:30 09:15 derrick. 6/20/2018 6/20/2018 0.50 PROD1 DRILL DHEQ T Shallow pulse lest MWD @ 225 gpm, 2,234.0 2,234.0 09:15 09:45 840 psi, 20 rpm, 7k. Good. 6/20/2018 6/20/2018 2.25 PROD1 DRILL TRIP T Continue RIH with BHA#13 from 2,234.0 7,578.0 09:45 12:00 2,234' MD to 7.578' MD, filling pipe every 20 stands. Annulus B=100 psi, Annulus C=0 psi @ 12:00 hrs. 6/20/2018 6/20/2018 2.25 PRODt DRILL TRIP T Continue RIH with BHA#13 from 7,578.0 11,007.0 12:00 14:15 7,578' MD to 11,007' MD filling pipe every 20 stands. 6/20/2018 6/20/2018 0.25 PRODt DRILL OWFF T Flow check, static. 11,007.0 11,007.0 14:15 14:30 1 1 1 1 SIMOPS- PJSM on pulling trip nipple. 6/20/2018 6/20/2018 0.50 PROD? DRILL MPDA T Pull trip nipple and install MPD 11,007.0 11,007.0 14:30 15:00 I element. Page 31147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time EM Time our (hr) phase Cp Code AC vity Cade Time P -T -X operation sten Depth MKB) End Depth (WS) 6/20/2018 6/20/2018 0.25 PROD1 DRILL MPDA T Wash/ ream down from 11,007' MD to 11,007.0 11,102.0 15:00 15:15 11,102' MD, breaking in bearing @ 50/100 rpm. Calibrate MPD chokes. P/U=205k, S/0=160k. 6/20/2018 6/20/2018 1.00 PROD1 DRILL TRIP T RIH from 11,107' MD to bottom @ 11,102.0 11,313.0 15:15 16:15 11,313' MD 6120/2018 6/20/2018 1.75 PROD1 DRILL DISP T PJSM, displace to 9.0 ppg MOBM. 11,313.0 11,313.0 16:15 18:00 Pumped 60 bbl spacer, followed by 9.0 ppg MOBM @ 250 gpm, 1400- 2740 psi, 60 rpm, 4.5-5.5k Tq. 6/20/2018 0.50 PRODi DRILL OWFF T Flow check, shut in MPD chokes 11,313.0 11,313.0 18:30 observe no pressure build. 6/20/2018 1.50 PRODi DRILL DDRL T Directional drill from 11,313' MD to 11,313.0 11,387.0 20:00 11,387' MD F20:00 6/20/2018 1.25 FROM DRILL OTHR T Troubleshoot MWD due not accepting 11,387.0 11,387.0 21:15 downlink. Tried sending single commands unsuccessful. Adjusted bypass rate on BPA to recommended start point 17 turns out, successful. 6/20/2018 6/21/2018 2.75 PRODt DRILL DDRL T Directional drill from 11,387' MD to 11,387.0 11,627.0 21:15 00:00 11,627' MD, 8,012' TVD. Tour ADT=3.7 hrs, P/U=193k, S/0=152k, ROT=170k, Tq on/off= 5k/5k, 215 gpm @ 220-0 psi, 100 rpm, 10.5 ECD. Annulus B=100 psi, Annulus C=0 psi @ 23:00 hrs. 6/21/2018 6121/2018 5.50 PROD1 DRILL DDRL T Directional drill from 11,627' MD to 11,627.0 12,087.0 00:00 05:30 12,087' MD, 6/21/2018 6121/2018 4.50 PRODt DRILL DDRL P Directional drill from 12,087' MD to 12,087.0 12,470.0 05:30 10:00 12,470' MD, 8,012' TVD. Tour ADT=10.3 hrs, PIU=200k, S/0=140k, ROT=165k, Tq on/off= 7.5k/6.5k, 218 gpm @ 2350 psi, 160 rpm, 10.75 ECD. Annulus 13=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/21/2018 6/21/2018 2.00 PROM DRILL DDRL P Directional drill from 12,470' MD to 12,470.0 13,249.0 10:00 12:00 12,626' MD, 8,013' TVD. Tour ADT=10.3 hrs, PIU=200k, S/0=140k, ROT=165k, Tq on/o8= 7.5k/6.5k, 218 gpm @ 2350 psi, 160 rpm, 10.75 ECD. Annulus 13=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/21/2018 6/22/2018 12.00 PROD1 DRILL DDRL P Directional drill from 12,626' MD to 12,626.0 13,249.0 12:00 00:00 13,249' MD, 8,007' TVD. ADT=10.1 hrs, P/U=196k, S/0=133k, ROT=162k, Tq on/oft= 8k/3.5k, 215 gpm @ 2370 psi, 180 rpm, 10.75 ECD. Annulus 13=100 psi, Annulus C=50 psi @ 23:00 hrs. 6/22/2016 6/2212018 10.00 PRODt DRILL DDRL P Directional drill from 13,249' MD to 13,249.0 13,785.0 00:00 10:00 13,785' MD, 7,981' TVD. ADT=8.1 hrs, P/U=212k, S/0=135k, ROT=165k, Tq on/off= 8k/6k, 215 gpm @ 2340 psi, 160 rpm, 10.87 ECD. Drilled out of zone into Kingak/ boundry from 13,409'-13,585' MD due significant dip change. -140 gAPI, splintered fragile cuttings. Turned up from 88° to 96" to get back in zone. Observed pump pressure and ECD spikes at 13,770', decision to POOH and wipe Kingak section for evaluation. Page 32147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Siert Time End Time Dur (hr) Phase Op Code A Wdy Code Time P -T -X Operation (aKB) I End Depth (KKB) 6/22/2018 6/22/2018 0.50 PROD1 DRILL BKRM T Backream out of hole from 13,785' MD - 13,785.0 13,769.0 10:00 10:30 to 13,769' MD @ 215 gpm, 2340 psi, 100 rpm, 6.5k Tq. Holding 10.5 ppg CBHP with MPDE. 6/22/2018 6/22/2018 1.50 PRODt DRILL PMPO T Pump out from 13,769' MD to 13,593' 13,769.0 13,593.0 10:30 12:00 MD @ 2 bpm, 960 psi. Packing off @ 13,636'to 1140 psi. Slack off to 13,648' and break over, continue pump out, packing off @ 13,593' twice. Slack off to 13,674' and break over. P/U=220-245k, S/0=135 -118k. Annulus B=100 psi, Annulus C=50 psi @ 12:00 hrs. 6/22/2018 6/22/2018 2.00 PROD1 DRILL PMPO T Continue pumping/stripping out from 13,593.0 13,293.0 12:00 14:00 13,674' MD to 13,293' MD. Pumping @.5-1 bpm, 700--800 psi. Holding 500 psi annular pressue with MPDE. Packing off and pulling tight @ 13,548', 13,537',13,413'. 6/22/2018 6/22/2018 2.00 PRODt DRILL CIRC T Circulate and condition, stage up from 13,293.0 13,293.0 14:00 16:00 24 gpm to 215 gpm, 940-2360 psi, stage rotary up to 140 rpm, 8.5k Tq. Shale returns at shakers. 6/22/2018 6/22/2018 1.50 PROD1 DRILL PMPO T Pump out of hole from 13,293' MD to 13,293.0 12,435.0 16:00 17:30 12,435' MD @ 3 bpm, 1000 psi. Maintaining 10.5 ppg EMW with MPDE. P/U=200k, S/0=155k, ROT=165k. 6/22/2018 6/22/2018 4.25 PROD1 DRILL KOST T Trough for open hole side track from 12,435.0 12,470.0 17:30 21:45 12,435' MD to 12,470' MD @ 215 gpm, 2160 psi, 100 rpm 60 fph @ 100% down until sleeve rotation observed, as well as slight drop in incinalion. Close AutoTrak ribs and make final pass to 12,470' MD. 6/22/2018 6/22/2018 0.50 PROD1 DRILL KOST T At 12,470' MD bit depth, circulate at 12,470.0 12,470.0 21:45 22:15 base of trough 215 gpm, 2160 psi, 100 rpm, 7k Tq. 6/22/2018 6/23/2018 1.75 PROD1 DRILL KOST T Begin time drilling per plan from 12,470.0 12,471.0 22:15 00:00 12,470' MD to 12,470.5' MD, 8,008' TVD. 215 gpm, 2160 psi, 100 rpm, 7k Tq. ADT=2.3, ECD=10.44, P/U=200k, S/0=1 50k, R0T=165k. Annulus 13=100 psi, Annulus C=50 psi @ 22:00 hrs. 6/23/2018 6/23/2018 12.00 PROD1 DRILL KOST T Time drill per Baker recommendation 12,471.0 12,481.0 00:00 12:00 from 12,470.5' MD to 12,481' MD, 8,013' TVD. ADT=12 hrs, ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2200 psi. ECD=10.44 Annulus B=100 psi, Annulus C=100 psi @ 12:00 hrs. 6/23/2018 6/24/2018 12.00 PROD? DRILL KOST T Continue to time drill per Baker 12,481.0 12,498.0 1200 00:00 recommendation from 12,481' MD to 12,498' MD, 8,014' TVD. ADT=11.9 hrs, ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2200 psi. ECD=10.49. Observe inclination drop to 88.78°, vs old well bore @ 89.75°. Annulus B=150 psi, Annulus C=100 psi @ 22:00 hrs. Page 33147 ReportPrinted: 7116/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sten Depen StenT ne Ertl Time Dur(hr) Phew Op Code Activity Code Tme P -T -X Operedon (ftKB) End Depen (ftKB) 6/24/2018 6/24/2018 5.00 PROD? DRILL KOST T Continue to control drill per Baker 12,498.0 12,530.0 00:00 05:00 recommendation from 12,498' MD to 12,530' MD, 8,014' TVD. ROT=175k, Tq=7.5k, 100 rpm, 215 gpm @ 2260 psi. ECD=10.49. Observe inclination drop to 88.70°, vs old well bore @ 90.65°. 6/24/2018 6/24/2018 7.00 PROD1 DRILL DDRL T Drill ahead from 12,530' MD with ribs 12,530.0 12,765.0 05:00 12:00 open, holding 89° and slight LH walk to achieve further separation from PB2. Drill from 12,530' MD to 12,756' MD, 8,013' TVD. TourADT=11.2 hrs. ROT=167k, Tq on/off-7k/6.5k, 160 rpm, 215 gpm @ 2260 psi. ECD=10.63. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/24/2018 6/25/2018 12.00 PROD1 DRILL DDRL T Drill ahead from 12,765' MD to 13,198' 12,765.0 13,198.0 12:00 00:00 MD, 7,989' TVD. TourADT=10.5 hrs. P/U=193k, S/0=133k, ROT=167k, Tq on/off--7k/6k, 160 rpm, 215 gpm @ 2370 psi. ECD=10.79. Annulus B=110 psi, Annulus C=100 psi @ 22:00 hrs. 6/25/2018 6/25/2018 6.25 PROD1 DRILL DDRL T Drill ahead from 13,198' MD to 13,785' 13,198.0 13,785.0 00:00 06:15 MD, P/U=193k, S/0=133k, ROT=167k, Tq on/off--7k/6k, 160 rpm, 215 gpm @ 2370 psi. ECD=10.79. 6/25/2018 6/25/2018 5.75 PROD1 DRILL DDRL P Drill ahead from 13,785' MD to 14,085' 13,785.0 14,085.0 06:15 12:00 MD, 7,954' TVD. Tour ADT=10.0 hrs. PIU=195k, S10=130k, ROT=162k, Tq on/off-7.5k/6.5k, 160 rpm, 215 gpm @ 2430 psi. ECD=10.69. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/25/2018 6/26/2018 12.00 PROD1 DRILL DDRL P Drill ahead from 14,085' MD to 14,849' 14,085.0 14,849.0 12:00 00:00 MD, 7,914' TVD. Tour ADT=9.7 hrs. P/U=190k, S/0=127k, ROT=160k, Tq on/off--8.8k/7.5k, 160 rpm, 215 gpm @ 2590 psi. ECD=11.09. Annulus B=175 psi, Annulus C=100 psi @ 22:00 hrs. 6126/2018 6/26/2018 1.25 PROW DRILL DDRL P Drill ahead from 14,849' MD to 14,912' 14,849.0 14,912.0 00:00 01:15 MD, 7,915' TVD P/U=190k, S/0=125k, R0T=160k, Tq on/off-8.5k/7.5k, 160 rpm, 215 gpm @ 2550 psi. ECD=10.9. 6126/2018 6/26/2018 0.50 PRODt DRILL CIRC P Circulate open hole volume, 80 bbl @ 14,912.0 14,912.0 01:15 01:45 215 gpm, 2530 psi, 120 rpm, 7.5k Tq. P/U=188k, S/0=133k, ROT=155k. SIMOPS- PJSM on C/O wash pipe. 6126/2018 6126/2018 0.50 PROD1 DRILL SVRG P Service rig, change out wash pipe on 14,912.0 14,912.0 01:45 02:15 top drive. Circulate @ 3 bpm 1300 psi via head pin, while holding 245 annular pressure with MPDE. 6/26/2018 6/26/2018 2.00 PROD1 DRILL DDRL P Drill ahead from 14,912' MD to 15,103' 14,912.0 15,103.0 02:15 04:15 MD, 7,923' TVD. Observe MPD element wom to where bearing not spinning on DP. 6/26/2018 6126/2018 0.50 PRODt DRILL CIRC P Circulate open hole volume, 90 bbl @ 15,103.0 15,103.0 04:15 04:45 215 gpm, 2510 psi, 100 rpm, 7k Tq. P/U=188k, S/0=133k, ROT=155k. SIMOPS- PJSM on C/O MPD bearing assy. Page 34147 Report Printed: 7/16/2018 Operations Summary (with Timelog Depths) MT6-O5 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log seen Depth Start Tim End Tie our (hr) Phaee Op Code A Vdy Code Time P -T -X Operation (ftKB) End Depth (ftKB) 6/26/2018 6/26/2018 0.50 PROD? DRILL MPDA P Change out MPD element. Shut down 15,103.0 15,103.0 04:45 05:15 mud pump, Gose chokes trapping 550 psi. Close annular preventer, open MPD chokes. Strip pipe through annular to C/O bearing. Close MPD chokes, equalize presures, open annular, 500 psi still holding in annulus. 6/26/2018 6/26/2018 6.75 PROD1 DRILL DDRL P Drill ahead from 15,103' MD to 15,810' 15,103.0 15,810.0 05:15 12:00 MD, 7,931' TVD. Tour ADT=8.2 hrs. P/U=195k, S/0=120k, ROT=155k, Tq ontoft=9.5k/8k, 160 rpm, 215 gpm @ 2630 psi. ECD=10.98. Annulus B=150 psi, Annulus C=100 psi @ 12:00 hrs. 6/26/2018 6/27/2018 12.00 PROD1 DRILL DDRL P Drill ahead from 15,810' MD to 16,514' 15,810.0 16,514.0 12:00 00:00 MD, 7,899' TVD. Tour ADT=9.6 hrs. P/U=195k, S/0=120k, ROT=158k, Tq onloff=9k/7k, 160 rpm, 215 gpm @ 2830 psi. ECD=11.27. Annulus 6=150 psi, Annulus C=100 psi @ 22:00 his. Losses to formation 120 bbl today, currently 6-9 bph seepage loss. Adding fine backgeround LCM. Observing wellbore breathing after 16,159' MD, where seepage loss increased, as well as change in drilling parameters (WOB) and log data.(Res increase). 6/27/2018 6/27/2018 2.50 PROM DRILL DDRL P Drill ahead from 16,514' MD to 16,730' 16,514.0 16,730.0 00:00 02:30 MD, 7,899' TVD P/U=195k, S/0=120k, ROT=158k, Tq on/off--8.5k/7.5k, 160 rpm, 215 gpm @ 2900 psi. ECD=11.3. 6/27/2018 6/27/2018 1.75 PRODI DRILL SEQP T Troubleshoot MWD surface 16,730.0 16,730.0 02:30 04:15 equipment, computer crashed. Re- boot, no go. Tech services remote in and repair corrupted file, re -boot good. SIMOPS- Circulate bottoms up @ 215 gpm, 2730 psi, 100 rpm, 8k Tq. 6/27/2018 6/27/2018 5.25 PROD1 DRILL DDRL P Drill ahead from 16,730' MD to 17,284' 16,730.0 17,284.0 04:15 09:30 MD, 7,891' TVD PIU=195k, S/0= (Lost SOW @ 17,199'), ROT=165k, Tq on/off=11k/8.5k, 160 rpm, 215 gpm @ 2930 psi. ECD=11.48. Tour ADT=6.0 hrs. 6/27/2018 6/27/2018 2.50 PROD1 DRILL CIRC P Circulate and condition hole for 17,284.0 17,284.0 09:30 12:00 fingerprint, 215-250 gpm, 2880-3550 psi, 100-120 rpm, 8-8.5k Tq. SPR's and on bottom survey. Circulate until 9.0 ppg in/out. Annulus B=200 psi, Annulus C=100 psi @ 12:00 hrs. 6/27/2018 6/27/2018 0.50 PROM DRILL OWFF P Perform MPD drawdown and 17,284.0 17,284.0 12:00 12:30 formation fingerprint, rotating string @ 20 rpm, 8k. OWFF, no pressure build, static with 9.0 ppg. 6/27/2018 6/27/2018 1.50 PROM DRILL DDRL P Drill ahead from 17,284' MD to 17,391' 17,284.0 17,35-10- 12:30 14:00 MD, 7,884' TVD P/U=195k, SIO= N/A, ROT=165k, Tq onloff=1lk/9k, 160 rpm, 215 gpm @ 2900 psi. ECD=11.33. Tour ADT=1.3 hrs. 6/27/2018 6/27/2018 1.00 PROM CASING CIRC P Circulate and condition @ 250 gpm, 17,391.0 17,391.0 14:00 15:00 2570 psi, 120 rpm, 8k Tq. Reciprocate from 17,391' MD to 17,294' MD Page 35147 ReportPrinted: 7/1 612 01 8 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time our (m) Phaea Op Code A ,Aty Code Time P -T-% Operation (ftKB) End Depth(RKB) 6/27/2018 6/27/2018 5.00 PROD1 CASING CIRC P Rack back stand to 17,294' MD, 17,391.0 17,294.0 15:00 20:00 continue circulating @ 220 gpm 2570 psi, 120 rpm, 8k Tq while weighting up to 9.3 ppg. Rack back second stand to 17,199' MD. Obtain SIO wt @ 125k. 6/27/2018 6/27/2018 0.50 PRODt CASING CIRC P At 9.3 ppg in/out, obtain SPR's. Test 17,294.0 17,199.0 20:00 20:30 floats (leaking). Blow down top drive. 6/27/2018 6/27/2018 0.50 PRODt CASING OWFF P Observe well for flow, static 30 17,199.0 17,199.0 20:30 21:00 minutes @ 9.3 ppg. 6/27/2018 6127/2018 1.50 PROD1 CASING SMPD P SOOH with 100 psi AP in slips, 260 17,199.0 16,150.0 21:00 22:30 psi pulling @ 1000 fph from 17,199' MD to 16,150' MD. Floats still leaking slowly, able to keep up using dg vac hose —6 It down DP before pulling. Observe correct hole fill. 6/27/2018 6127/2018 0.50 PROD1 CASING CIRC P Pump 50 bbl 12.0 ppg dry job @ 215 16,150.0 16,150.0 22:30 23:00 gpm, 2400 psi, 10 rpm 6k, blow down lop drive. 6/27/2018 6/28/2018 1.00 PROD1 CASING SMPD P Continue to SOOH from 16,150' MD to 16,150.0 15,610.0 23:00 00:00 15,610' MD pulling dry pipe. P/U=205k, ROT=175k. Calc Fill=9 bbl, Actual 1111=12 bbl. Annulus B=100 psi, Annulus C=100 psi @ 22:00 hrs. Daily seepage loss to formation=130 bbl, Cumulative Interval=574 bbl 6/28/2018 6/28/2018 4.25 PROD1 CASING SMPD P Continue to SOOH from 15,610' MD to 15,610.0 11,007.0 00:00 04:15 11,007' MD holding 290 psi annular back pressure pulling and 100 psi in slips. Checking slack off weight every 10 stands, 125k, 140k, 147k, 150k, 152k. 6/28/2018 6/28/2018 2.00 PROD1 CASING CIRC P Circulate casing clean @ 200 gpm, 11,007.0 11,007.0 04:15 06:15 2350 psi, 120 rpm, 5-6k Tq. Capture slug comin g out of hole, increase rate to 250 gpm, 2770 psi. Pump 80 bbl 10.7+ slug into pipe. Blow down top drive. P/U=192k, S/0=155k, ROT=165k. 6/28/2018 6/28/2018 0.75 PROD1 CASING OWFF P OWFF static, drop 2.11" OD hollow 11,007.0 11,007.0 06:15 07:00 drift with tail on stand #112. 6/28/2018 6/28/2018 5.00 PROD? CASING SMPD P Continue to SOOH from 11,007' MD to 11,007.0 2,043.0 07:00 12:00 2,043' MD holding 290 psi annular back pressure pulling and 100-30 psi in slips. Annulus B=75 psi, Annulus C=0 psi @ 12:00 hrs. 6/28/2018 6/28/2018 0.50 PROD1 CASING CIRC P Circulate bottoms up @ 2,043' MD, 5 2,043.0 2,043.0 12:00 12:30 1 1 1 bpm 1200 psi. Dump slug from hole. 6/28/2018 6/28/2018 0.25 PROD1 CASING OWFF P Monitor well for flow, 15 minutes static 2,043.0 2,043.0 12:30 12:45 prior to pulling RCD. PJSM on pulling RCD. 6/28/2018 6/28/2018 0.75 PROD1 CASING MPDA P Pull RCD bearing, install trip nipple. 2,043.0 2,043.0 12:45 13:30 Change out trip nipple air boot. 6/28/2018 6/28/2018 1.00 PROD1 CASING TRIP P POOH on elevators from 2,043' MD to 2,043.0 332.0 13:30 14:30 332' MD. P/U=90k. OWFF-Static. 6/28/2018 6/28/2018 0.50 PROD1 CASING BHAH P Lay down Jar, PIU HWDP joint and 332.0 177.0 14:30 15:00 make stand HWDP. Rack back/ 2 stands HWDP for liner run. 6/28/2018 6/28/2018 2.00 PROD1 CASING BHAH P PJSM, Lay down BHA #13 and 177.0 0.0 15:00 17:00 sources from 177' MD. Total losses from SOOH=40 bbl, static loss=0. Page 36147 Report Printed: 7/1612018 Uperations Summary (with Timelog Depths) MT6-05 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) EM Depth (Wit) 6/28/2018 6/28/2018 0.50 PRODi CASING BHAH P Clean and clear rig floor. 0.0 0.0 17:00 17:30 6/28/2018 6/28/2018 0.50 COMPZ11 WHDBOP RURD P Pull wear bushing, FMC set test plug 0.0 0.0 17:30 18:00 and 4" test joint. 6/28/2018 6/28/2018 1.00 COMPZ11 WHDBOP RURD P Rig up test equipment, flood system 0.0 0.0 18:00 19:00 with water and purge air from system. 6/28/2018 6/28/2018 3.50 COMPZ1 WHDBOP BOPE P Perform AOGCC BOPE test, 0.0 0.0 19:00 22:30 witnessed by Adam Earl. BLM Mutasim Elganzoory waived 6/22 16:29 hrs via email. 4" and 4W' Test joints, 250/3500 psi 5 min as charted. 4" TJ, tested Annular preventer, CV #1,12,13,14.4" Demco Kill, Upper (Auto) IBOP, Upper 3%i' x 6" VBR, HCR Kill, CV#9,11. Manual (Lower) IBOP. CV# 5,8,10, XT39 Dart Valve, CV# 4,6,7. XT39 FOSV, CV#2. HCR choke, manual choke, manual kill, Lower 3%" x 6" VBR. 41/V Test It, test Annular preventer, Upper and lower 3%" x 6" VBR's. 6/28/2018 6/28/2018 1.00 C0MPZ1 WHDBOP BOPE P Perform accumulator function test. 0.0 0.0 22:30 23:30 System pressure=3050 psi, Manifold pressure=1450 psi. System pressure after functioning all rams, annular and HCR valves=1400 psi, manifold=1180 psi. 200 psi attained= 25 seconds with electric pump, full system recovery= 155 seconds with electric and air pumps. 4 bottle Nitrogen average=2150 psi. Test blind rams 250/3500. Test manual and super auto choke to 1100 psi. Tested rig gas alarms, flow paddle and PVT's. 6/28/2018 6/29/2018 0.50 COMPZ1 WHDBOP RURD P Pull test plug, blow down/ rig down 0.0 0.0 23:30 00:00 test equipment. Annulus B=75 psi, Annulus C=0 psi 22:00 hrs. 6/29/2018 8/29/2018 0.25 COMPZ1 WHDBOP RURD P Set 6.1875" wear ring per FMC. 0.0 0.0 00:00 00:15 SIMOPS- Blow down mud line. 6/29/2018 6/29/2018 1.00 COMPZ1 CASING RURD P R/U to run 4%' TXP liner, C/O to 4W 0.0 0.0 00:15 01:15 Tubing elevators, P/U and R/U double stack power tongs. Count pipe and verify running order. 6/29/2018 6/29/2018 6.50 COMPZ1 CASING PUTB P PJSM, P/U 31A" orange peel joint, P/U 0.0 6,118.0 01:15 07:45 and run 4W TXP liner and perf pups per detail to 6,118' MD. 6/29/2018 6/29/2018 1.50 COMPZ1 CASING PUTB P Change out elevators to 4", P/U HRDE 6,118.0 6,162.0 07:45 09:15 ZXP liner top packer and Flex Lock liner hanger easy. Make up 2-3/8" slick seal and ball seat easy. Make up SLB SCMT tools to botttom of liner running tools. Mix and pour Zanplex, RIH to 6,162' MD. P/U=120k, S/0=110k. 6/29/2018 6/29/2018 0.50 COMPZ1 CASING RUNL P Make up XO to 4" DP, RIH with first 6,162.0 6,271.0 09:15 09:45 stand from 6,162' MD to 6,271' MD from derrick. 6/29/2018 6/29/2018 0.25 COMPZI CASING CIRC P Establish circulation @ 1-3 bpm, 60- 6,271.0 6,271.0 09:45 10:00 180 psi to ensure circulation path clear. P/U=120k, S/0=110k. 6/29/2018 6/29/2018 2.00 COMPZ11 CASING RUNL P Run liner on 4" DP from 6,271' MD to 6,271.0 9,508.0 10:00 12:00 9,508' MD. S/0=125k. 6/29/2018 6/29/2018 1.50 COMPZ1 CASING TRIP P Continue to run liner in hole with 4'A" 9,508.0 10,949.0 12:00 13:30 liner on drill pipe from 9,508' MD to 10,949' MD. Page 37147 Report Printed: 7/16/2018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur (hr) Phase op Code Activity Cede Time P -T -X Operation (Wit) End Depth (M(S) 6/29/2018 6/29/2018 0.50 COMPZ1 CASING CIRC P Obtain parameters @ window. Break 10,949.0 10,949.0 13:30 14:00 circulation @ 3 bpm, 580 psi, circulate 9.3 ppg even MW in/out. P/U=175k, S/0=145k, ROT=160k. Check tating torque @ 10 rpm=3.5k, 20 rpm=3.7k. 6/29/2018 6/29/2018 4.50 COMPZ1 CASING TRIP P Continue running in hole from 10,949' 10,949.0 17,192.0 14:00 18:30 MD to set depth 17,192' MD. Liner lop @ 11,034' MD. P/U=225k, S/O=150k. 6/29/2018 6/29/2018 1.00 COMPZ1 CASING PACK P Drop 1.625" setting ball, pump down 17,192.0 17,192.0 18:30 19:30 @ 3 bpm, 930 psi for 60 bbl, slow rate to 1.5 bpm 520 psi. Ball on seat @ 77 bbl. Increase pressure to 2100 psi. Slack off to 100k observe hanger set. Pressure up to 3650 psi and hold 5 min. Bleed off. P/U and observe free travel @ 215k. S/O and observe shear @ 110k. Repeat. PIU to 190k, seals still located. 6/29/2018 6/29/2018 0.50 COMPZ1 CASING PRTS P Rig up and pressure test liner top 17,192.0 17,192.0 19:30 20:00 packer to 3300 psi for len minutes charted. 6/29/2018 629/2018 0.50 COMPZ1 WELLPR TRIP P POOH to 11,095' (Running tools 17,192.0 11,095.0 20:00 20:30 length) MD @ 215k to cut and slip. SCMT still in liner. 6/29/2018 6/29/2018 1.00 COMPZ1 WELLPR SLPC P PJSM, cut and slip 68' of drilling line, 11,095.0 11,095.0 20:30 21:30 calibrate block height. 6/29/2016 6/30/2018 2.50 COMPZ1 WELLPR QEVL P POOH with SCMT logging tools from 11,095.0 9,450.0 21:30 00:00 11,095' MD to 9,450' MD, logging out 1500 fph. P/U=200k, Calc Fill=15 bbl, Actual Fill=20 bbl. Annulus B=75 psi, Annulus C=0 psi @ 22:00 hrs. 6/30/2018 6/30/2018 1.50 COMPZ1 WELLPR QEVL P POOH from 9,450' MD to 8,112' MD, 9,450.0 8,112.0 00:00 01:30 logging with SCMT @ 1500-1800 fph. P/U=175k. 6/30/2018 6/30/2018 0.50 COMPZ1 WELLPR CIRC P Break circulation, pump 18 bbl 11.1 8,112.0 8,112.0 01:30 02:00 ppg slug @ 3 bpm, 550 psi. Blow down top drive. 6/302018 6/30/2018 5.00 COMPZ1 WELLPR TRIP P POOH from 8,112' MD to 104' MD. 8,112.0 104.0 02:00 07:00 Total Calc Fill=81 bbl, Actual Fill=90.5 bbl. 6/302018 6/30/2018 0.25 COMPZ1 WELLPR OWFF P OWFF- Static, PJSM on laying down 104.0 104.0 07:00 07:15 1 1 liner running tools and SCMT. 6/30/2018 6/30/2018 1.00 COMPZ1 WELLPR SHAH P Lay down Baker liner running tools 104.0 0.0 07:15 08:15 and SLB logging tools from 104' MD 6/30/2018 6/30/2018 0.50 COMPZ1 WELLPR BHAH P Clean and clear dg floor, lay down 0.0 OA 08:15 08:45 tools off floor. 6/30/2018 6/30/2018 3.25 PROD2 WHPST BHAH P PJSM, Make up Whipstock / Mill 0.0 81.0 08:45 12:00 assembly per Baker reps. 6/30/2018 6/302018 1.50 PROD2 WHPST BHAH P Continue making up whipstock BHA to 81.0 337.0 12:00 13:30 337' MD 6/30/2018 6/302018 0.50 PROD2 WHPST TRIP P Trip in hole from 337' MD to 1,537' 337.0 1,537.0 13:30 14:00 MD, S/0=80k. 6/30/2018 6/302018 0.50 PROD2 WHPST DHEQ P Shallow pulse test MWD @ 200 gpm, 1,537.0 1,537.0 14:00 14:30 820 psi. Good. 6/30/2018 6/30/2018 5.00 PROD2 WHPST TRIP P Continue tripping in hole from 1,537' 1,537.0 8,726.0 14:30 19:30 MD to 8,726' MD. S/0=150k, P/U=175k. 6/30/2018 6/30/2018 0.50 PROD2 WHPST DLOG P Establish circulation @ 8,726' MD, 8,726.0 8,750.0 19:30 20:00 200 gpm 1500 psi. Log RA lag @ 8,586' MD casing depth. Page 38147 Report Printed: 7116/2018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log $tart Deptn Siert Time End Time our Qn) Pheee Op code Activey Code Time P -T -X Operation QIKS) End Dept, (WB) 6/30/2018 6/30/2018 1.50 PROD2 WHPST TRIP P Continue tripping in hole from 8,750' 8,750.0 10,917.0 20:00 21:30 MD to 10,917' MD. P/U=185k, S/0=150k. 6/30/2018 6/30/2018 1.25 PROD2 WHPST WASH P Establish circulation and wash down 10,917.0 11,012.0 21:30 22:45 @ 200 gpm, 1760 psi. Orient whipstock slide @ 13°L, slowly work pipe to work down any rotational movement. 6/30/2018 6/30/2018 0.25 PROD2 WHPST WASH P Made connection @ 11,012' MD, still 11,012.0 10,939.0 22:45 23:00 @ 13°L. Continue washing down and No -Go with 4k down @ 11,035' MD (seal assy @ 11,039'). Slack off 15k and observe Anchor shear set. PIU 1 Ok over to confirm trip anchor set. Slack off 35k, observe whipstock trip bolt shear. Pick up above TOW with 185k. TOW=1 0,939.14'MD, BOW=10,952.44, TOL=11,035' MO drill pipe measurement. 6/30/2018 7/1/2018 1.00 PROD2 WHPST MILL P Begin milling window from 10,939' MD 0,939.0 10,939.0 23:00 00:00 to 10,939.65' MD @ 220 gpm, 2080 psi, 80 rpm, 4-5k Tq. 0-1k Weight on mill, ROT=167k. Annulus B=0 psi, Annulus C=75 psi @ YY 22:00 hrs. 7/1/2018 7/1/2018 4.25 PROW WHPST MILL P Continue milling window from 10,939.0 10,952.0 00:00 04:15 10,939.65' MD to 10,952.44' MD @ 220 gpm, 2020 psi, 100 rpm, 5-8k Tq, 15-18k WOB. I TOW= 10,939.14' MD, BOW=10,952.44' MD. 7/1/2018 7/1/2018 4.75 PROD2 WHPST DDRL P Continuie drilling formation to 10,973' 10,952.0 10,973.0 04:15 09:00 MD with same parameters, second and third mill pass through window. 7/1/2018 7/1/2018 0.50 PROD2 WHPST REAM P Ream up and down through window 10,973.0 10,916.0 09:00 09:30 @ 220 gpm, 2020 psi, 100 rpm, 5k Tq. P_/U=180k, S/0=154k, ROT=165k. Shut down rotary. work mills up and down through window @ 1 bpm, 440 psi. P/U=190k, S/0=156k. Smooth, no obstructions. 7/1/2018 7/1/2018 1.25 PROD2 WHPST CIRC P OWFF static. Pump 30 bbl HV Super 10,916.0 10,916.0 0930 1045 Sweep @ 200 gpm, 1900 psi, pump surface to surface sweep out of the hole, minor increase in mill cutting returns. 7/1/2018 7/1/2018 0.25 PROD2 WHPST OWFF P Obtain SPR's, OWFF- Static 10,916.0 10,916.0 10:45 11:00 7/1/2018 7/1/2018 1.00 PROD2 WHPST TRIP P POOH on elevators from 10,916' MD 10,916.0 10,058.0 11:00 12:00 to 10,058' MD. P/U=190k. 7/1/2018 7/1/2018 6.50 PROW WHPST TRIP P Continue POOH on elevators from 10,058.0 241.0 12:00 18:30 10,058' MD to 241' MD. P/U=90k. OWFF- Sialic. Calc/Actual fill= 73 bbl. 7/1/2018 7/1/2018 1.50 PROD2 WHPST BHAH P PJSM, Lay down milling BHA. 241.0 0.0 18:30 20:00 Magnets fully loaded, Pilot mill 1/2" under gauge, upper mill in gauge. 7/1/2018 7/1/2018 0.50 PROD2 WHPST BHAH P Lay down BHA tools from rig floor, 0.0 0.0 20:00 20:30 Clean and clear rig floor. Page 39147 Report Printed: 7/16/2018 Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Star) Depth Start End Time our (hr) Phase Op Code Aolivlty Cade Time P -T -X Operation (flKB) End Depth (flKB) 7/1/2018 7/1/2018 1.00 PROD2 WHPST WWWH P Make up stack washer with Baker 0.0 0.0 2030 21:30 magnets. Function blind rams. RIH with magnets, fuction VBR's. Flush stack @ 10 bpm, 20 rpm for 15 minutes, significant cuttings/shavings over shakers. Flush until shakers clean. Clean magnets, lay down stack washer. 7/1/2018 7/1/2018 0.50 PROD2 WHPST SVRG P Service top drive rollers, block, 0.0 0.0 21:30 22:00 washpipe, crown, draworks, iron roughneck. 7/1/2018 7/1/2018 1.00 PROD2 WHPST BHAH P PJJSM, M/U BHA#1510 76' MD. 0.0 76.0 2200 23:00 MWD scribe to motor high side offset 23.9°. Verify offset. Annulus B=0 psi, Annulus C=70 psi @ 22:00 hrs. 7/1/2018 7/2/2018 1.00 PROD2 WHPST BHAH P Continue M/U BHA#15 to 564' MD 76.0 564.0 2300 0000 7/2/2018 7/2/2018 0.75 PROD2 WHPST BHAH P Continue M/U BHA#15 from 564' MD 564.0 771.0 0000 00:45 to 771' MD (HWDP and Jars) 7/2/2018 7/2/2018 0.50 PROD2 WHPST TRIP P Trip in hole from 771' MD to 1,720' MD 771.0 1,720.0 0045 01:15 out of derrick. 7/2/2018 7/2/2018 0.25 PROD2 WHPST DHEO P Shallow pulse test MWD @ 215 gpm, 1,720.0 1,720.0 01:15 01:30 1000 psi - Good. 7/2/2018 7/2/2018 4.25 PROD2 WHPST TRIP P Continue RIH from 1,720' MD to 1,720.0 8,591.0 01:30 0545 8,591' MD filling pipe every 20 stands. 7/2/2018 7/2/2018 0.25 PROD2 WHPST DLOG P Break circulation, log from 8,591' MD 8,591.0 8,683.0 0545 0600 to 8,683' MD @ 220 gpm, 1600 psi, 150 fph to log RA tag. P/U RA tag @ 8,626' MD bit depth (8,584' casing depth) 7/2/2018 7/2/2018 1.50 PROD2 WHPST TRIP P Continue RIH from 8,683' MD to 8,683.0 10,875.0 0600 0730 10,875' MD filling pipe every 20 stands. P/U=187k, S/0=150k, Calc/ Actual Disp=72 bbl. 7/2/2018 7/2/2018 0.25 PROD2 WHPST CIRC P Break circulation 220 gpm, 1660 psi. 10,875.0 10,875.0 0730 0745 Obtain SPR's. Orient motor to 10°L. 7/2/2018 7/2/2018 1.00 PROD2 DRILL TRIP P Shut down pumps, slide through 10,875.0 10,973.0 0745 0845 window with no pump or rotary to 10,973' MD. No obstructions. 7/2/2018 7/2/2018 3.25 PROD2 DRILL DDRL P Directional drill (kick off) from 10,973' 10,973.0 11,113.0 08:45 1200 MD to 11,113' MD, 7,999' MD. ADT=2.4, ART=.5, AST=1.9 hrs. Obtain surveys @ TOW and BOW (10,939'-10,952' MD.) P/U=187k, S/0=155k, ROT= 160k, Tq on/off=5.5k/5k. 7/2/2018 7/2/2018 0.50 PROD2 DRILL DDRL P Directional drill (kick off) from 11,113' 11,113.0 11,161.0 12:00 12:30 MD to 11,161' MD, 7,974' MD. ADT=0.5, ART=0.5, AST=0.0 hrs. P/1 -1=1901k, S/0=150k, ROT=164k, Tq on/off=6.5k/5k. 7/2/2018 7/2/2018 1.50 PROD2 DRILL CIRC P Circulate bottoms up @ 215 gpm, 11,161.0 11,161.0 1230 1400 2260 psi, 80 rpm, 5.5k Tq. Take final survey, obtain SPR's. 7/2/2018 7/2/2018 0.50 PROD2 DRILL BKRM P Backream out of hole @ drilling rates 11,161.0 10,970.0 14:00 1430 215 gpm, 60 rpm from 11,161' MD to 11,065' MD. Stop rotary and pump out from 11,065'to 10,970' MD orient motor high side to 10°L. P/U=190k. Page 40/47 ReportPrinted: 7/16/2018 operations Summary (with Timelog Depths) 411 MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth start Time End Tune our (hr) Phase Op Code ActivityCode Time P -T -X Operation (11KB) EM Depta (flKB) 7/2/2018 7/2/2018 0.50 PROD2 DRILL TRIP P Pull BHA across window from 10,970' 10,970.0 10,847.0 14:30 15:00 MD to 10,847' MD with no pumps or rotary. P/U=1 90-1 94k, no overpull. Monitor well - Static. PJSM on installing RCD. 7/212018 7/2/2018 0.50 PROD2 DRILL MPDA P Pull trip nipple and install RCD. 10,847.0 10,847.0 15:00 15:30 7/2/2018 712/2018 0.50 PROD2 DRILL CIRC P Pump 30 bbl 10.7 ppg slug @ 5 bpm, 10,847.0 10,847.0 15:30 16:00 1930 psi. 7/2/2018 7/2/2018 6.25 PROD2 DRILL SMPD P Strip out with MPD from 10,847' MD to 10,847.0 2,006.0 16:00 22:15 2,006' MD holding 290 psi annular back pressure while pulling and 30 psi in slips. 7/2/2018 7/2/2018 0.25 PROD2 DRILL OWFF P OWFF- Static 2,006.0 2,006.6- 22:15 22:30 SIMOPS- PJSM on pulling RCD, installing trip nipple. Annulus B=0 psi, Annulus C=75 psi 22:00 hrs. 7/2/2018 7/22018 0.50 PROD2 DRILL MPDA P Pull RCD, install trip nipple. 2,006.0 2,006.0 22:30 23:00 722018 72/2018 0.75 PROD2 DRILL TRIP P POOH on elevators from 2,006' MD to 2,006.0 771.0 23:00 23:45 771' MD. Calc Fill for trip=65 bbl, Actual Fill=84 bbl. 7122018 7/32018 0.25 PROD2 DRILL OWFF P Monitor well Q HWDP for flow, slight 771.0 771.0 23:45 00:00 trickle, diminishing. 7132018 7132018 0.25 PROD2 DRILL OWFF P FIC (statc) - PJSM on UD BHA 771.0 771.0 00:00 00:15 7/3/2018 7/32018 2.25 PROD2 DRILL BHAH P UD kick off BHA as per Baker reps. 771.0 0.0 00:15 02:30 7/3/2018 7/3/2018 0.50 PROD2 DRILL SHAH P Clean & clear floor of BHA tools & 0.0 0.0 02:30 03:00 equipment. 7/3/2018 7/3/2018 3.75 PROD2 DRILL SHAH P M/U 6" production RSS BHA as per 0.0 329.0 03:00 06:45 Baker eps to 329' 7/312018 7/312018 0.25 PROD2 DRILL TRIP P RIH f/329'to 420' 329.0 420.0 06:45 07:00 7/3/2018 7/312018 0.75 PROD2 DRILL SFTY P Install anti slip safety mats on rig floor. 420.0 420.0 07:00 07:45 7/3/2018 7/3/2018 1.00 PROD2 DRILL TRIP P RIH f/420'to 2,231' 420.0 2,231.0 07:45 08:45 7/3/2018 7/3/2018 0.50 PROD2 DRILL DHEQ P Shallow hole test MWD tools w/200 - 2,231.0 2,231.0 08:45 09:15 225 gpm 11060 - 1300 psi. 7/312018 7/3/2018 6.25 PROD2 DRILL TRIP P RIH f/2,231'to 8,560' (Culling DP as 2,231.0 8,560.0 09:15 15:30 needed) 7/3/2018 7/3/2018 0.50 PROD2 DRILL DLOG P Log RA tag f18,560'to 8,622'w/220 8,560.0 8,622.0 15:30 16:00 gpm / 1980 psi. RA tag on depth 7/3/2018 713/2018 1.00 PROD2 DRILL TRIP P RIH f/8,622'to 10,813' 8,622.0 10,813.0 16:00 17:00 7/32018 7/3/2018 1.00 PROD2 DRILL SLPC P Slip & cut drill line. Calibrate block 10,813.0 10,813.0 17:00 18:00 height. 7/3/2018 7/32018 0.50 PROD2 DRILL SVRG P Service rig 10,813.0 10,813.0 18:00 18:30 7/32018 7/312018 0.50 PROD2 DRILL MPDA P Pull trip nipple & install RCD bearing 10,813.0 10,813.0 18:30 19:00 7/3/2018 7/3/2018 1.50 PROD2 DRILL DISP P Pump 75 bbls high vis sweep & 10,813.0 10,813.0 19:00 20:30 displace well to new 9.0 ppg OBM 7/3/2018 7/3/2018 0.50 PROD2 DRILL OWFF P Close chokes & monitor well for flow. 10,813.0 10,813.0 20:30 21:00 (Static) 7/312018 7/3/2018 0.50 PROD2 DRILL TRIP P RIH f/10,81310 11,050'. No issues 10,813.0 11,050.0 21:00 21:30 across whipstock. 7/312018 7/3/2018 0.50 PROD2 DRILL REAM P W&R f/11,050'to 11,161'w/215 gpm / 11,050.0 11,161.0 21:30 22:00 1 1 1 1970 psi, 50 rpm / 5 k trq Page 41147 Report Printed: 7/16/2016 = Uperations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Siert TIM End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKa) End Depth (k(a) 7/3/2018 7/4/2018 2.00 PROD2 DRILL DDRL P Drill ahead f/11,161'to 11,275'MD/ 11,161.0 11,275.0 22:00 00:00 7,960' TVD, ADT 1.1 Hrs, ECD 10.12 ppg, 215 gpm, 2060 psi, PU wt 190 k, SO wt 150 k, ROT wt 165 k, 90 rpm, 6/5 k trq, 7/412018 7/4/2018 12.00 PROD2 DRILL DDRL P Drill ahead f111,275'to 12,147' MD / 11,275.0 12,147.0 00:00 12:00 7,954' TVD, ADT 10.1 Hrs, ECD 10.38 ppg, 210 gpm, 2160 psi, PU wt 195 k, SO wt 138 k, ROT wt 165 k, 120 rpm, 7/5 k trq, 7/412018 7/5/2018 12.00 PROD2 DRILL DDRL P Drill ahead f/12,147'to 13,090' MD / 12,147.0 13,090.0 12:00 00:00 7,913' TVD, ADT 10 Hrs, ECD 10.52 ppg, 210 gpm, 2300 psi, PU wt 200 k, SO wt 140 k, ROT wt 165 k, 120 rpm, 7.516 k trq, 7/512018 7/5/2018 1200. PROD2 DRILL DDRL P Drill ahead f/13,090' to 14,053' MD / 13,090.0 14,053.0 00:00 12:00 7,925' TVD, ADT 9.1 Hrs, ECD 10.88 ppg, 225 gpm, 2630 psi, PU wt 195 it, SO wt 130 k, ROT wt 160 k, 130 rpm, 8.617 k trq, 71512018 7/612018 12.00 PROD2 DRILL DDRL P Drill ahead f/14,053' to 15,004' MD / 14,053.0 15,004.0 12:00 00:00 7,884' TVD, ADT 10 Hrs, ECD 11.23 ppg, 220 gpm, 2740 psi, PU wt 200 k, SO wt 125 k, ROT wt 162 k, 130 rpm, 9.5/7 k trq, 7/612018 7/612018 2.25 PROD2 DRILL DDRL P Drill ahead f/15,004' to TD of 15,195' 15,004.0 15,195.0 00:00 02:15 MD / 7,888' TVD, ADT 1.9 Hrs, ECD 11.14 ppg, 220 gpm, 2770 psi, PU wt 200 k, SO wt 125 k, ROT wt 158 k, 130 rpm, 9/7.5 k trq, 7/612018 7/6/2018 0.25 PROD2 CASING CIRC P Pump up final survey & obtain torque 15,195.0 15,195.0 02:15 02:30 and drag parameters. 7/6/2018 7/6/2018 2.00 PROD2 CASING CIRC P Circ 2 B/U w/220 gpm 12770 psi, 130 15,195.0 15,004.0 02:30 04:30 rpm 17.5 k Inc. Racked back 1 stand per B/U 7/6/2018 7/6/2018 0.25 PROD2 CASING OWFF P Perform formation draw down. Rotate 15,004.0 15,004.0 04:30 04:45 15 rpm. No psi increase (static) 7/6/2018 7/6/2018 3.00 PROD2 CASING CIRC P Wt up to 9.3 ppg w/220 gpm 12700 - 15,004.0 14,909.0 04:45 07:45 2860 psi, 130 rpm / 7 k trq. Racked back 1 stand. 7/612018 7/6/2018 0.25 PROD2 CASING OWFF P Rotate 15 rpm & F/C (static). Line up 14,909.0 14,909.0 07:45 08:00 Ito Strip OOH 7/6/2018 7/612018 5.00 PROD2 CASING SMPD P Strip OOH as per MPD schedule 14,909.0 10,813.0 08:00 13:00 f/14,909'to 10,813'. No issues pulling BHA thm window. 7/6/2018 7/6/2018 1.00 PROD2 CASING CIRC P Circ B/U w/220 gpm / 2320 psi, 80 10,813.0 10,813.0 13:00 14:00 rpm 14.5 k trq. 7/612018 7/6/2018 0.50 PROM CASING OWFF P FIC (static) 10,813.0 10,813.0 14:00 14:30 71612018 7/6/2018 6.50 PROD2 CASING SMPD P Strip OOH as per MPD schedule 10,813.0 1,278.0 14:30 21:00 f/10,813'to 1,278' 7/6/2018 7/612018 0.50 PROM CASING OWFF P F/C (static)-SIMOPS clean floor 1,278.0 1,278.0 21:00 21:30 716/2018 7/612018 0.50 PROD2 CASING MPDA P Pull RCD bearing & install trip nipple. 1,278.0 1,278.0 21:30 22:00 7/6/2018 7/6/2018 1.00 PROD2 CASING TRIP P POOH f/ to 1,278'to 329' 1,278.0 329.0 22:00 23:00 7/6/2018 7/6/2018 0.25 PROD2 CASING OWFF P FIC (static) 329.0 329.0 23:00 23:15 7/612018 7/712018 0.75 PROM CASING TRIP P POOH f/329' to 143'. UD jar stand 329.0 143.0 23:15 00:00 7f712018 7/712018 2.00 PROD2 CASING BHAH P PJSM. Remove sources & UD BHA as 143.0 0.0 00:00 02:00 1 I per Baker reps. Page 42147 Report Printed: 711612018 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Activity Oode Time P -T -X Operatian (MKB) End DepU mKB) 717/2018 7/7/2018 1.00 PROD2 CASING BHAH P Clean & dear floor 0.0 0.0 02:00 03:00 7/7/2018 7/7/2018 1.00 COMPZ2 FISH SHAH P Cont. to clean & clear floor. Mobilize 0.0 0.0 03:00 04:00 BHA to rig floor. 7/7/2018 717/2018 1.50 COMPZ2 FISH BHAH P M/U whipstock retrieval BHA as per 0.0 241.0 04:00 05:30 Baker reps. 7/7/2018 7/7/2018 1.50 COMPZ2 FISH TRIP P RIH f/241' to 2,144' 241.0 2,144.0 05:30 07:00 7/7/2018 7/7/2018 0.50 COMPZ2 FISH DHEO P Shallow hole test MWD w/180 gpm / 2,144.0 2,144.0 07:00 07:30 680 psi 7/7/2018 7/7/2018 6.00 COMPZ2 FISH TRIP P RIH f/2,144'to 10,726' 2,144.0 10,726.0 07:30 13:30 7/7/2018 7/7/2018 0.25 COMPZ2 FISH OWFF P FIC (static) 10,726.0 10,726.0 13:30 13:45 7/72018 717/2018 0.50 COMPZ2 FISH MPDA P Pull trip nipple & install RCD bearing 10,726.0 10,726.0 13:45 14:15 717/2018 7/7/2018 0.50 COMPZ2 FISH WASH P Wash down f/10,726'to 10,949'w/180 10,726.0 10,949.0 14:15 14:45 gpm 11400 psi. Orient jet to wash whipstock slot. PU wt 185 k / SO wt 145 k 7/712018 7/712018 1.00 COMPZ2 FISH FISH P Orient latch to whipstock slot. Latch up 10,949.0 10,917.0 14:45 15:45 on whipstock. Attempt to straight pull. No success. Set down 10 k WOB & cock jars. P/U to 225 k & fire jars. Attempt to straight pull. No success. Set down 10 k WOB & cock jars. P/U to 250 k & fire jars. Straight pull to 285 k & release anchor. Pull whipstock free to 10,917' 7/72018 7/7/2018 1.25 COMPZ2 FISH CIRC P Circ B/U w/180 gpm 11440 psi. 10,917.0 10,917.0 15:45 17:00 7/7/2018 7/7/2018 0.25 COMPZ2 FISH OWFF P F/C (static) 10,917.0 10,917.0 17:00 17:15 7/7/2018 7/8/2018 6.75 COMPZ2 FISH SMPD P Strip OOH as per MPD schedule 10,917.0 4,235.0 17:15 00:00 f/10,91 T to 4,235' 7/8/2018 7/8/2018 2.25 COMPZ2 FISH SMPD P Strip OOH as per MPD schedule 4,235.0 1,859.0 00:00 02:15 f/4,235'to 1,859 7/8/2018 718/2018 0.25 COMPZ2 FISH OWFF P F/C (static) PJSM on MPD 1,859.0 1,859.0 02:15 02:30 7/8/2018 7/8/2018 0.50 COMPZ2 FISH MPDA P Pull RCD bearing & install trip nipple. 1,859.0 1,859.0 02:30 03:00 7/8/2018 7/8/2018 1.00 COMPZ2 FISH TRIP P POOH f/1,859'to 337' 1,859.0 337.0 03:00 04:00 7/82018 7/8/2018 3.00 COMPZ2 FISH BHAH P UD whipstock retrieval BHA & 337.0 0.0 04:00 07:00 whipstock. 7/8/2018 7/82018 3.00 COMPZ2 FISH SHAH P Clean & clear rig floor of OBM & BHA 0.0 0.0 07:00 10:00 tools & equipment. UD 1 stand of 15.7# DP & P/U 1 stand of HWDP. 7/8/2D18 7/8/2018 2.25 COMPZ2 CASING RURD P R/U to run liner. R/U power tongs, 4- 0.0 0.0 10:00 12:15 112" slips & elevators. M/U safety XO. 7/8/2018 718/2018 6.75 COMPZ2 CASING PUTB P P/U & RIH 4-1/2" 12.6# L-80 TXP liner 0.0 4,081.0 12:15 19:00 to 4,081'. (98 jts liner & 15 pert pups) 7/812018 7/8/2018 1.75 COMPZ2 CASING OTHR P MIU SLB slim hole MWD tools & 4,081.0 4,121.0 19:00 20:45 Baker hook hanger assembly & liner running tools to 4,121'. (MWD offset 266°) PU wt 100 k / SO wt 95 k 7/82018 7/8/2018 1.00 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/4,121'to 4,121.0 5,547.0 20:45 21:45 5,547' 7/8/2018 7/812018 0.50 COMP72 CASING DHEO P Shallow hole test MWD tools w/100 5,547.0 5,547.0 21:45 22:15 gpm / 600 psi 7/8/2018 7/9/2018 1.75 C0MPZ2 CASING RUNL P RIH% -1/2" liner on DPf/5,547'to 5,547.0 8,879.0 22:15 00:00 I g,g7g' Page 43147 Report Printed: 7/161201W e Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Siert Time Entl lime our (hr) Phase Op Cotle ANviry Cotle Time P -T -X Operathn Sian Depth (MB) End Depth (fiKB) 7/9/2018 7/9/2018 1.50 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/8,879'—to 8,879.0 10,939.0 00:00 01:30 10,939' 7/9/2018 7/9/2018 1.00 COMPZ2 CASING RUNL P Attempt to run liner out window. Stack 10,939.0 11,069.0 01:30 02:30 out on top of lower liner top @ 11,034'. Pick up to above window & apply 3/4 turn & work down. Attempt to run liner out window. Stack out on top of lower liner top @ 11,034'. P/U & place liner shoe across window. Rotate liner w/5 rpm & observe trq spike of 4.3 k when liner shoe bumps window. Release torque & slack oft to 11,069'& confirm liner exited window. 7/9/2018 7/9/2018 3.50 COMPZ2 CASING RUNL P RIH w/4-1/2" liner on DP f/11,069'to 11,069.0 15,039.0 02:30 06:00 15,039'. PU wt 225 k / SO wt 150 k 7/9/2018 7/9/2018 3.25 COMPZ2 CASING HOSO P Orient hook hanger to high side & 15,039.0 10,934.0 06:00 09:15 slack off past bottom of window. Pick up hook to above window. Orient hook to low side. S/O and hang hook on window with 30 k WOB. Repeat twice & confirm hook on window. Drop 29/32" ball & pump down w/2.8 bpm / 1290 psi, slow pumps to 1 bpm / 550 psi. Ball on seat W95 bbls. Pressure up to 3500 psi & release from hook hanger assy as per Baker rep. Blow ball seat. Top of hook assy @ 10,934.82' 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR TRIP P POOH f/10,934'to 10,855'. Observe 10,934.0 10,795.0 09:15 10:15 swabbing. Pump OOH f/10,855'to —0 10,795' Discuss options with town 7/9/2018 7/9/2018 25 COMPZ2 WELLPR OWFF P F/C (static) 10,795.0 10,795.0 10:15 10:30 7/9/2018 7/9/2018 1.00 COMPZ2 WELLPR SLPC P Slip & cut 58' drill line. SIMOPS - circ 10,795.0 10,795.0 10:30 11:30 —1 & cond mud w/3 bpm / 830 psi 7/9/2018 7/9/2018 00 COMPZ2 WELLPR SVRG P Service rig, top drive & draw works. 10,795.0 10,795.0 11:30 12:30 SIMOPS - circ & cond mud w/3 bpm / 830 psi 7/9/2018 7/9/2018 0.25 COMPZ2 WELLPR SLPC P Calibrate block hight 10,795.0 10,795.0 12:30 12:45 7/9/2018 7/9/2018 0.50 COMPZ2 WELLPR OW FF P F/C (static) 10,795.0 10,795.0 12:45 13:15 7/9/2018 7/9/2018 1.00 COMM WELLPR TRIP P Attempt to POOH f/10,795'to 10,611'. 10,795.0 10,611.0 13:15 14:15 Observe swabbing. Discuss options with town. Decision made to displace to brine. 7/9/2018 7/9/2018 0.75 60MPZ2 WELLPR TRIP P RIH f/10,611'to 10,850' 10,611.0 10,850.0 14:15 15:00 7/9/2018 7/9/2018 1.50 COMM WELLPR RURD P Clean pits, pipe racks & rig floor in 10,850.0 10,850.0 15:00 16:30 preparation for displacement Build brine segregation pill. 7/9/2018 7/9/2018 1.00 (OMPZ2 WELLPR DISP P Spot 20 bbl OBM / brine segregation 10,850.0 10,750.0 16:30 17:30 pill f/10,850' to 10,750'w/3 bpm 1820 psi. 7/9/2018 7/9/2018 3.50 COMPZ2 WELLPR DISP P Pump 59 bbl 10.45 ppg spacer, 31 bbl 10,750.0 10,750.0 17:30 21:00 deep clean spacer, 38 bbl high vis spacer & displace well to 9.2 ppg brine w/3 - 3.5 bpm / 820 - 400 psi. 7/9/2018 7/9/2018 0.50 COMM WELLPR OWFF P F/C (static). SIMOPS - Clean under 10,750.0 10,750.0 21:00 21:30 1 1 1 shakers after displacement. 7/92018 7/9/2018 0.50 COMPZ2 WELLPR RURD P Cont. to dean under shakers after 10,750.0 10,750.0 21:30 22:00 1 1 displacement. 7/9/2018 7/10/2018 2.00 COMPZ2 WELLPR TRIP P POOH f/10,750'to 9,155'. PU wt 180 k 10,750.0 9,155.0 22:00 00:00 Page 44147 Report Printed: 7116/2018 3 Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (m) Phase Op Code Activity Code Time P -T -X Operation Sten Deem (ftK8) End Depm(Wi 7/10/2018 7/10/2018 6.50 COMPZ2 WELLPR TRIP P POOH 1/9,155'to 102' 9,155.0 102.0 00:00 06:30 7/10/2018 7/10/2018 1.00 COMPZ2 WELLPR BHAH P UD liner running tools & slim pulse 102.0 0.0 06:30 07:30 tools. 7/10/2018 7/10/2018 0.50 COMPZ2 WELLPR SHAH P Clean & clear floor of BHA tools & 0.0 0.0 07:30 08:00 equipment. 7/10/2018 7/10/2018 1.00 COMPZ2 RWRID TURD P R/U to run LEM. R/U power tongs, 4- 0.0 0.0 08:00 09:00 1 1 1/2" slips & elevators. M/U safety XO. 7/10/2018 7/10/2018 1.75 COMPZ2 RWRID BHAH P MIN seal easy, LEM, & ZXP w/SLB 0.0 247.0 09:00 10:45 slim pulse to 247' (MWD offset 116°, LEM high side) 7/10/2018 7/10/2018 1.25 COMPZ2 RWRID TRIP P RIH w/LEM assy f/247'to 2,149' 247.0 2,149.0 10:45 12:00 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID DHEQ P Shallow hole test MWD tools w/100 2,149.0 2,149.0 12:00 12:30 gpm / 250 psi 7/10/2018 7/10/2018 1.00 COMPZ2 RWRID TRIP P RIH w/LEM assy f/2,149'to 4,243' 2,149.0 4,243.0 12:30 13:30 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID SVRG P Service dg & iron roughneck 4,243.0 4,243.0 13:30 14:00 7/10/2018 7/10/2018 5.25 COMPZ2 RWRID TRIP P RIH vv/LEM assy 1/4,243'to 11,004' 4,243.0 11,004.0 14:00 19:15 -0 7/10/2018 7/10/2018 75 COMPZ2 RWRID CIRC P Break circ w/100 gpm 1500 psi. Orient 11,004.0 11,004.0 19:15 20:00 LEM 28° left. 7/10/2018 7/10/2018 0.25 COMPZ2 RWRID HOSO P Wash down w/100 gpm 1500 psi 11,004.0 11,049.0 20:00 20:15 f/11004'to 11,049'. Set 30 k WOB & latch up LEM to hook. P/U to 215 k & slack off to 35 k WOB & confirm latch. 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID PACK P Drop 1.625" ball & pump down w/2.6- 11,049.0 11,049.0 20:15 20:45 2 bpm / 500 - 300 psi. Ball on seat @ 77 bbls. Pressure up to 2500 psi to set packer& hold for 5 min. Increase psi -2 to 3560 psi & observe roti shift. 7/10/2018 7/10/2018 50 C0MPZ2 RWRID PACK T R/U & attempt to pressure test packer. 11,049.0 11,049.0 20:45 23:15 Start pressuring up & at 1000 psi it appears we are injection fluid and not building anymore pressure. Packer appears to not be set. Check all surface equipment & perform 2000 psi pressure test on surface (good). Attempt to pressure test packer again with same result. Manually attempt to set packer without rotation. Attempt to pressure test again without success. Discuss options with town. Manually attempt to set packer & saw a second shift & packer appeared to set. 7/10/2018 7/10/2018 0.50 COMPZ2 RWRID PRTS P Pressure test packer to 3000 psi & 11,049.0 10,814.0 23:15 23:45 chart for 10 min (good). 7/10/2618 7/11/2018 0.25 COMPZ2 RWRID TRIP P POOH to above packer sealbore to 10,814.0 10,759.0 23:45 00:00 10,759' (Top of sealbore @ 10,813.94') 7/11/2618 7/11/2018 1.75 COMPZ2 RWRID CIRC P Circ B/U 2.5 - 4 bpm / 250 - 530 psi. 10,759.0 10,759.0 00:00 01:45 7/11/2018 7/11/2018 0.25 COMPZ2 RWRID OWFF P F/C(static) 10,759.0 10,759.0 01:45 02:00 7/11/2018 7/11/2018 11.00 COMPZ2 RWRID PULD P POOH & UD DP f/10,759'to 86. 10,759.0 86.0 02:00 13:00 (Culled out bad jts of pipe) 7/11/2018 7/11/2018 1.00 COMPZ2 RWRID BHAHP UD Baker running tools & SLB slim 86.0 0.0 13:00 14:00 pulse MWD. Clean & clearWFloor. 7/11/2018 7/11/2018 0.75 COMPZ2 WHDBOP WWH P Flush stack w/deep dean. 14:00 14:45 Page 45/47 Report Printed: 7116120181 . Operations Summary (with Timelog Depths) MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time D., (h,) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (RKB) End Depth(MB) 7/11/2018 7/11/2018 1.25 COMPZ2 WHDBOP RURD P Pull wear ring & set test plug as per 0.0 0.0 14:45 16:00 FMC. R/U to test BOPE. fill stack -6 w/H20 & purge lines. 7/11/2018 7/11/2018 25 C0MPZ2 WHDBOP BOPE P Test BOPE 25013500 for 5/10 min's 0.0 0.0 16:00 22:15 w/4" & 4-1/2" test joints. Annular, 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4-112" X 7" VBR's, lower 3-1/2" X 6" VBR's & blind rams, 4" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3100 psi, final 1450 psi, 1 st 200 psi recharge = 29 sec's, full recharge = 149 second. 4 bottles @ 2250 psi. Gas alarms, PVT alarms and flow indicated tested. Draw down on manual & super choke. AOGCC Matt Herrera & BLM Mutasim Elganzoory waived witness via email. 7/11/2018 7/11/2018 0.50 C0MPZ2 WHDBOP RURD P R/D testing equipment & B/D lines. 0.0 0.0 22:15 22:45 Pull test plug. 7/11/2018 7/12/2018 1.25 C0MPZ2 RPCOMP RURD P R/U to run completion. R/U power 0.0 0.0 22:45 00:00 tongs, tubing slips & elevators. R/U Carrico control line. 7/12/2018 7/12/2018 1.25 C0MPZ2 RPCOMP RURD P Cont. to R/U to run completion. R/U I- 0.0 0.0 00:00 01:15 wire sheaves. Bring cannon clamps to floor. 7/12/2018 7/12/2018 16.25 C0MPZ2 RPCOMP RCST P RIH 4-1/2" 12.6# L-80 Hyd 563 upper 0.0 10,763.0 01:15 17:30 completion to 10,763' PU wt 157 k / SO wt 131 k 7/12/2018 7/12/2018 1.75 C0MPZ2 RPCOMP HOSO P M/U space out jts. R/U head pin & 10,763.0 10,763.0 17:30 19:15 break circ w/1 bpm @ 40 psi. Wash in hole & observe psi increase once seals in seal bore. Shut down pumps & cont to RIH & no-go out w/10 k WOB @ 10,822.62'. POOH & L/D space out jts. 7/12/2018 7/12/2018 1.75 C0MPZ2 RPCOMP THGR P M/U space out pups & M/U hanger. 10,763.0 10,805.0 19:15 21:00 M/U landing jt A. Terminate I wire & pressure test fitting to 5000 psi. RIH w/hanger to 10,805' (seal assy 2' above seal bore) 7/12/2018 7/12/2018 1,50 COMPZ2 RPCOMP CRIH P Pump 25.5 bbls CI brine & chase 10,805.0 10,805.0 21:00 22:30 w/160 bbls 9.2 brine w/4.5 bpm / 400 psi. (20.5 bbls Cl brine outside pipe & 5 bbls inside). SIMOPS - R/D & L/D Carron equipment. 7/12/2018 7/12/2018 0.25 C0MPZ2 RPCOMP OWFF P F/C (static) 10,805.0 10,805.0 22:30 22:45 7/12/2018 7/13/2018 1.25 C0MPZ2 RIP THGR P RIH & land on hanger @ 10,818.651. 10,805.0 10,818.0 22:45 00:00 (3.97' from fully located). Remove blind flange & verify alignment. RILDS. Test hanger seals 250 psi 15 min & 5000 psi / 10 min on chart. 7/13/2018 7/13/2018 0.50 C0MPZ2 RPCOMP THGR P Cont. to test hanger seals 5000 psi / 0.0 0.0 00:00 _T/1 00:30 10 min on chart. 3/2018 7/13/2018 3.25 C0MPZ2 RPCOMP PRTS P R/D head pin. Drop ball & rod. R/U 0.0 0.0 00:30 03:45 head pin. Test surface lines to 3800 psi (good). Test tubing to 3500 psi & chart for 30 min (good). Bleed down tubing to 2000 psi. Test IA to 3300 psi & chart for 30 min (good). Bleed off pressure. Pressure up on IA & shear SOV @ 1800 psi. Break circ w/1 bpm @ 430 psi. Page 46147 ReportPrinted: 7/16/2018 Operations Summary (with Timelog Depths) Fe MT6-05 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (fiKS) End Depth(ftKB) 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP RURD P R/D cement hose. B/D lines & UD 0.0 0.0 03:45 04:15 -landing jointA 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP OWFF P Fill stack w/H20 & F/C for 30 min 0.0 0.0 04:15 04:45 (static). SIMOPS -LID power tongs 7/13/2018 7/13/2018 1.00 COMPZ2 RPCOMP MPSP P Install HP-BPV Install landing joint B. 0.0 0.0 04:45 0545 Test in direction of flaw 2500 psi for 15 min (good). L/D landing joint B 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP OWFF P F/C for 30 min (static). SIMOPS - C/O 0.0 0.0 05:45 06:15 elevators. M/U stack washer. 7/13/2018 7/13/2018 0.50 COMPZ2 RPCOMP WWWH P Flush stack. UD stack washer. 0.0 0.0 06:15 06:45 7/13/2018 7/13/2018 0.75 COMPZ2 RPCOMP RURD P B/D lines. B/D choke. L/D excess 0.0 0.0 06:45 0730 completion tools from rig floor/ UD (- wire spool. 7/13/2018 7/13/2018 6.25 COMPZ2 WHDBOP NUND P Remove trip nipple & Floor plates. 0.0 0.0 07:30 1345 Clean drip pan &Flow box. N/D Flow line, flow box, Katch Kan & MPD valves. 7/13/2018 7/13/2018 2.75 COMPZ2 WHDBOP NUND P Break ram doors for BWM. Remove 0.0 0.0 13:45 16:30 kill & choke lines. N/D BOPE & rack back on pedestal. SIMOPS - C/O saver sub on top drive. 7/13/2018 7/13/2018 1.75 COMPZ2 WHDBOP NUND P SLB terminate ]-wire through tree. 0.0 0.0 16:30 1815 FMC install smooth bore metal seal. Install test dart in BPV profile. 7/13/2018 7/13/2018 1.25 COMPZ2 WHDBOP NUND P N/U tree adaptor. Unable to seat 0.0 0.0 18:15 19:30 properly. PIU jt HWDP &set down w/14 k WOB to seat. Secure flange. 7/13/2018 7/13/2018 2.00 COMPZ2 WHDBOP PRTS P FMC test flange to 5000 psi (good). 0.0 0.0 19:30 21:30 Fill tree w/diesel & test 250 & chart for 10 min. (Downhole readings f/Camco = 3779 psi @ 174T) 7/13/2018 7/13/2018 1.00 COMPZ2 WHDBOP PRTS T Attempt to test tree to 5000 psi. Fluid 0.0 0.0 21:30 22:30 leaking from test hose fitting. C/O fitting. Test tree to 5000 psi & chart for 10 min. (good) 7/13/2018 7/13/2018 0.50 COMPZ2 WHDBOP MPSP P FMC pull dart from BPV. Secure well. 0.0 0.0 22:30 23:00 Tubing, IA, IOA, = 0 psi. OA = 75 psi. (Little red will FP off-line once rig is moved) 7/13/2018 7/13/2018 0.50 DEMOB MOVE RURD P Clean misc tools & equipment from 0.0 0.0 23:00 23:30 cellar. Set 90' mouse hole. R/U to UD DP 7/13/2018 7/14/2018 0.50 DEMOB MOVE PULD P UD 5 stands 4" DP racked back in 0.0 0.0 23:30 00:00 derrick via 90' mouse hole. 7/14/2018 7/14/2018 7.75 DEMOB MOVE PULD P L/D 81 stands 4" DP racked back in 0.0 0.0 00:00 07:45 derrick via 90' mouse hole. 7/14/2018 7/14/2018 0.50 DEMOB -MOVE TURD P C/O handle equipment to 5". Pull 0.0 0.0 07:45 08:15 mouse hole. 7/14/2018 7/14/2018 3.75 DEMOB -MOVE RURD P Clean& clear rig floor & cellar. Prep for 0.0 0.0 08:15 12:00 move. Move away ball mill 8:45 Hrs. Move away pits/motors complex 10:30 Hrs. Rig released 12:00 Hrs Page 47/47 Report Printed: 7/16/2018 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05 50-103-20771-00 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 BAT(ER UGHES a GE company �. ConocoPhillips SA ER ConocoPhjl6 p S LUGNES Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project Wastem North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMTI Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual Of 9) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MTB -05 Database: EDT 14 Alaska 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) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-05 Well Position *NIS 0.00 usft Northing: 5,945,543.79usft Latitude: 70° 16'22.964 N -E/JW 0.00 usft Easing: 317,059.98usft Longitude: 151° 28'42.930 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00usft Ground Level: 37.20 usft Wellbore MT6-05 Magnetics Model Name Sample Date Deepnagon Dip Angle Field Strength (1) 11 (nT) BGGM2017 5/20/2018 16.50 8D.72 57,422 Design MT6-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,406.40 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 320.71 8/15/2018 5.00,04PM Pape 2 COMPASS 5000.14 Build 85 CortocoPhillips ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MTe-05 TVDSS Project: Western North Slope TVD Reference: MTS -05 Actual @ 88.70usft (Actual D19) DLS Site: GMT1 Lookout Pad MD Reference: MT6.05 Actual C 88.70usft (Actual D19) (usR) Well: MT6-05 Northing Norm Reference: True Section Survey Tool Name Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Ift) Database: EDT 14 Alaska Production 36.50 Survey Program 0.00 Data 52.20 0.00 0.00 From To 0.00 0.00 UNDEFINED 60.26 Survey (usfl) (usf) Survey (Wellbore) Tool Name Description Star) Date 60.26 263.26 GYD Gyro DMS 16" (MT6-0SPB7) GYD-CT-DMS Gyrodata cont.ddllpipe m/s 5/13/2018 296.26 1,957.96 BHGE MWD+IFR+MSA 16"(MT6-05PB7 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/15/2018 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4"(MT&05 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 5/21/2018 8,968.80 11,028.48 BHGE MWD+IFR+MSA 6x8-3/4"(MT6.0 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/4/2018 11,106.00 11,358.55 BHGE MWD INC 6" (MT6-05PB2) MWD -INC ONLY (INC>10-) MWD -INC ONLY_FILLER ( INC>10`) 6/22/2018 11,453.90 12,406.40 BHGE MWD+IFR+MSA6"(MT6-05PB2) MWD+IFR-AK-SC MWD+IFR AK CAZ SCC 6/22/2018 12,501.75 17,362.98 BHGE MWD+IFR+MSA 61(MT6.05) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 6/26/2018 Survey IND Inc AXI TVD TVDSS +N/S +FJ -W Map KUP DLS Vertical Wait) (ry(°) (uaR) (usR) (uaR) (ua Northing Eaagng (*M00,) Section Survey Tool Name IR) Ift) (ft) 36.50 0.00 0.00 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.26 0.33 231.64 60,26 -28.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.00 GYDCT-0MS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 41.36 5,945,643.27 317,059.61 0.22 -0.18 GYD-CT-0MS(1) 263.26 0.55 211.72 263.25 174.55 -1.26 -0.70 5,945,542.54 317,059.25 0.24 -0.53 GYD-CT-DMS(1) 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96 1.31 -0.62 MWD+IFR-AKCAZSC(2) 390.15 1.24 252.95 390.13 301.43 -2,46 -2.50 5,945,541.40 317,057.42 0.64 -0.32 MWD+IFRAKCAZ-SC(2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 1.65 MWD+IFR-AKCAZ4C(2) 577.56 3.84 299.00 577.36 488.66 0.13 5.59 5,945,544.16 317,050.40 1.76 6.18 MWD+IFRAKCAZSC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 13.6 MWD+IFRAKCAZSC(2) 766.06 7.00 304.80 764.99 676.29 9.88 -24.57 5,945,654.26 317,035.66 1.63 23.20 MWD+IFR-AKCAZSC(2) 860.61 8.03 306.69 858.72 770.02 17.11 54.60 5,945,561.73 317,025.81 1.12 35.15 MWD+IFRAKCAZ-SC(2) 955.24 8.96 307.34 952.31 863.61 25.53 45.76 5,915,570.42 317,014.86 0.99 48.73 MND+IFRAKCAZSC (2) 1,048.71 10.08 308.87 1,044.50 95580 35.08 57.91 5,945,580.26 317,002.94 1.23 63.82 MWD+IFRAKCAZSC (2) 1,143.88 11.57 39.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 81,33 MWD+IFRAKCAZSC(2) 1,238.25 12.95 310.96 1,230.19 1,141.49 59.31 57.07 5,945,605.19 316,974.39 1.50 101.04 MWD+IFRAKCAZSC(2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.85 5,945,620.06 316,957.95 1.25 122.86 MND+IFRAKCAZSC(2) BA ER F�UGHES Survey End Date 5/1312018 Annotation 8/152018 5:00.04PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. •WNS Local Coordinate Reference: Well MTB -05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual C 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey MD Inc AN TVD TVDSS +N1 -S +PJ -W Map Map Vertical (uelt) (7 1% Wait) (uslt) (ualt) (usfd Northing FaWng °10 ( ) Section Survey Tool Name (ft) (R) (R) 1,427.45 14.70 308.04 1,413.78 1,325.08 88.66 -122.06 5,945,635.38 - 316,940.10 0.89 145.92 MWD+IFR-AK-CAZSC (2) 1,521.38 15.39 305.44 1,509.49 1,415.79 103.23 -141.62 5,945,650.42 316,920.92 1.03 169.58 MWD+IFR-AK-CAZSC(2) 1,616.89 14.91 304.96 1,596.68 1,507.98 117.62 -162.02 5,946665.30 316,900.88 0.52 193.63 MNA+IFR-AK-CA2-SC (2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 217.06 MWD+IFR-AKCAZSC(2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202.82 5,945,695.69 316,860.80 1.48 242.23 MWD+IFR-AKCAZSC(2) 1,899.91 16.01 30258 1,968.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.39 MWD+IFR-AKCAZSC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 287.27 MWC),IFR-AKCAZSC (2) 2,014.00 19.29 307.93 1,976.66 1,887.98 186.34 -254.09 5,945,736.24 316,810.51 0.83 305.12 MWD+IFR-AKCAZSC(3) 2,050.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 316.98 MWD+IFR-AK-WSC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 329.92 MWDAFR-AXCAZSC(3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 501.15 5,945,774.29 316,764.37 2.55 363.49 MND+IFR-AKCAZSC(3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 531.10 5,945,798.93 316,735.00 2.78 400.98 MWD+IFR-AKCAZSC(3) 2,372.40 26.72 308.06 2,30651 2,217.81 272.74 -363.43 5,945,825.26 316,703.30 1.60 441.23 MWD+IFR-AKCAZSC(3) 2.467.33 27.46 308.78 2,391.02 2,302.32 299.60 597.30 5,995,852.94 316,670.10 0.85 483.47 MWD+IFR-AKCAZSC(3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 432.25 5,945,880.75 316,635.82 2.80 526.47 MWD+IFR-AKCAZSC(3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 469.44 5,945,909.21 316,599.32 1.14 571.36 MND+IFR-AKCAZSC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 -50633 5,945,939.34 316,661.15 1.05 618.58 MND+IFR-AKCAZSC (3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.56 667.29 MND+IFRAKCAZ-SC (3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 587.97 6.946.002.74 316,483.03 0.12 716.61 MWD+IFRAKCAZ-SC(3) 3,028.87 32.99 308.00 2,871.15 2.782.45 476.32 528.35 5,946,035.20 316,443.43 0.73 766.54 MWD+IFRAKCAZSC (3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.28 5,946,067.97 316,403.28 0.64 817.07 MWD+IFR-AKCAZSC (3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711,27 5,946,101.09 316,362.09 1.33 868.51 MVtU+IFR-AKCAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -764.68 5,996,134.96 316,319.49 0.78 921.41 MWD+IFRAKCAZSC(3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946,169.49 316,276.14 0.79 975.28 MWD+IFRAK-CAZ-SC(3) 3,500.89 36.47 306.40 3,257.86 3,169.16 640.06 543.65 5,946,204.11 316,232.18 0.59 1,029.61 MWD+IFRAKCAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 588.51 5,946,238.62 316,188.14 0.74 1,063.90 MND+IFRAK-CAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 -934.17 5,946,274.11 316,143.34 0.65 1,139.42 MWDAFRAKCAZSC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 -982.28 5,946,309.78 316,006.09 2.97 1,196.60 MND+IFRAKCAZSC(3) 3,877.30 40.94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1,255.11 MWD+IFR-AKCAZSC (3) 3,971.83 40.95 303.40 3,624.36 3,535.65 810.49 -1,084.82 5,946,380.33 $15,995.24 0.08 1,314.23 MWD+IFRAK-CAZSC(3) 4,065.45 40.97 303.86 3,695.06 3,606.36 844.47 -1,135.92 5,946,415.55 315,944.98 0.32 1,372.90 MND+IFRAKCAZSC(3) Annotation 13-3/8" x 16" BA�*,S 4 87152018 5:00:04PM Page 4 COMPASS 5000.14 Build 85 Survey MD ConocoPhillips Aid ConocoPhillips Definitive Survey Report +N/ -S Company: ConowPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MTS -05 Project: Westem North Slope TVD Reference: MT6-05 Actual @ 88.70usR (Actual D79) Site: GMT1 Lookout Pad MD Reference: MT6.05 Actual @ 88.70usR (Actual D79) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey MD Inc Aid NDSS +N/ -S +E/ -W Map Map DLS Vertical 5 (115M(ueft) (usR) (ueR) Northing Easfing (1/1001 Section Tool Name Annotation Survey (R) (ft) (R) 4,159.82 4209 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,45176 315,893.96 1.20 1,432.81 MWD+IFRAK-0AZSC(3) 4,254.03 43.41 305.40 3,834,89 3,746.19 915.89 -1,240.34 5,946,489.48 315,842.33 1.69 1,494.30 MWD+IFRAK-CAZSC(3) 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -1,292.10 5,946,528.52 315,791.50 2A4 1,556.33 MNAI+IFRAK-CAZ-SC (3) 4,444.53 45.64 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571.78 315,736.38 0.68 1,624.33 MWD+IFRAK-CAZSC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,693.25 MWDNFRAK-CAZSC(3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,759.33 MWD+IFRAK-CAZSC(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 0.75 1,823.28 MWD+IFRAK-CAZSC(3) 4,824.17 45.60 304.58 4,23660 4,146.90 1,154.17 -1,568.46 5,946,735.64 315,520.11 0.36 1,886.49 MWD+IFRAK-CAZSC(3) 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,946,774.89 315,465.10 0.71 1,951.26 MWD+IFR-AK-CAZSC(3) 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946813.73 315,410.16 0.33 2,015.66 MM+IFRAK-CAZSC (3) 5.106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1,735.77 5,946,852.98 315,355.62 0.42 2,050.14 MWD+IFRAK-CAZSC(3) 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,946,892.54 315,300.93 0.22 2,144.96 MWD+IFRAK-0AZSC(3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,209.76 MWD+IFRAK-CAZSC(3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.26 2,274.51 MWD+IFRAK-CAZSC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2,337.67 MWD+IFRAK-0AZ-SC (3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 31682.30 0.26 2,402.27 MWD+IFRAK-CAZSC(3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068,74 5,947,087.76 315,028.27 0.39 2,466.51 MWD+IFRAK-CAZSC (3) 5,766.67 45.12 306.17 4,898.71 4,808.01 1,533.09 -2123.09 5,947,127.89 314,974.88 0.95 2,630.97 MWD+IFRAK-CAZSC(3) 5,861.26 45.08 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,595.95 MWD+IFRAK-CAZSC(3) 5,953.99 45.13 307.58 _ 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,659.85 MWD+IFRAK-0AZSC(3) 6,048.44 45.D4 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,25226 314,818.82 0.10 2,724.99 MWD+IFR-AK-CAZSC(3) 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,789.86 MWD+IFRAK-CAZSC(3) 6,235.05 45.06 307.01 5,227.45 5,138.75 1,734.21 -2366.78 5,947,335.35 314.716.18 0.68 2,853.61 MWD+IFRAK40AZSC(3) 6,329.17 45.06 306,63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947,376.56 314,653.83 0.29 2,918.29 MWD+IFRAK-CAZSC(3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1,813.94 -2,493.85 5,947,417.65 314,611.08 0.16 2,983.12 MNA+IFRAK-CAZSC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2,547.50 5,947,458.46 314,558.40 0.09 3,047.68 MWD+IFRAK-CAZSC(3) 6,612.19 45.05 306.15 5,493.76 5,405.06 1,893.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,112.47 MWD+IFRAK-CAZSC(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3.176.88 MWD+IFRAK-CAZ-SC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5.947,580.62 314,399.25 0.16 3,241.85 MWD+IFRAK-CAZSC(3) 6,896.14 45.10 305.70 5,694.24 5.60654 2011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,306.94 MWD+IFRAK-CAZSC(3) 6,991.21 45.07 305.68 5,761 J6 5.672.66 2,050.40 -2,818.90 5,947,661.92 314,291.89 0.03 3,371.97 MWD+IFRAK-CAZSC (3) 8/15@018 5.00.04PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ER @ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -VMS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usfl (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70ush (Actual D19) Well: MT6-05 North Reference: True Wellbore: MTG-05 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EDT 14 Alaska Production Survey 8/1572018 5:00:04PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azl TVD TVDBS ♦W.5 +H -W DLS (usft) 11 Wait) Nam Well) Wall) Northing Easting ("1100' Section Survey Tool Name Annotation (ft) (to) (it) 7,085.78 45.08 305.19 5,828.15 5,739.45 2,069.22 -2,873.86 5,997,702.06 314,238.29 0.37 3,436.56 MWD+IFR-AKCAZSC (3) 7,179.83 45.10 305.01 5,894.55 5,805.85 2,127.52 -2,927.95 5,947,741.66 314,184.75 0.14 3,500.71 MWD+IFR-AK-CAZSC(3) 7,273.52 45.05 304.% 5,960.71 5,872.01 2,165.51 4,98233 5,947,780.96 314,131.31 0.13 3,564.55 MWD+IFR-AK-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 5,037.39 5,947,820.74 314,077.21 0.13 3,629.18 MWI)AFR- K-CAZSC(3) 7,462.04 45,09 305.22 6,093,82 6,005.12 2,242.13 5,091.64 5,947,86D.21 314,023.90 0.15 3,693.07 MNAHFR-AK-0AZSC (3) 7,665.32 45.01 304.78 6,159.73 6,071.03 2,280.00 -3,145.72 5,947,899.37 313,970.76 0.34 3,756.62 MWD+IFR-AK-CAZSC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 5,200.60 5,947,938.63 313,916.82 0.19 3,820.73 MWD+IFR-AK-CAZSC(3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 -3,254.29 5,947,977.43 313,864.06 0.66 3,883.77 MWD+IFR-AK-CAZSC(3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,948,017.64 313,810.38 0.35 3,948.63 MWD+IFR-AK-CAZSC(3) 7,930.75 45.27 305.88 6,424.41 6,335.71 2,433.69 4363.13 5,948,058.29 313,757.16 0.05 4,013.24 MWD+IFR-AK-CAZSC(3) 8,024.98 45.26 306.66 6,490.73 6,402.03 2,473.29 5,417.09 5,948,099.19 313,704.18 0.59 4,078.06 MWD+IFRAK-0AZSC(3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,513.32 5,470.51 5,948,140.50 313,651.75 0.29 4,142.88 MWD+IFRAWCAZSC(3) 8,212.40 45.10 306.82 6,622.70 6.539.00 2,553.17 5,523.53 5,948,181.63 313,599.72 0.27 4,207.29 MWD+IFRAX-CAZSC(3) 8,306.99 45.06 306.73 6.689.49 6,600.79 2,593.27 5,57718 5,948,223.01 313,547.06 0.08 4,272.30 MWD+IFRAKCAZSC(3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 5,630.98 5,948,263.96 313,494.25 0.50 4,337.06 MWD+IFR-AKCAZSC (3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 5,684.69 5,94$304.31 313,441.50 0.05 4,401.30 MWD+IFRAK-CAZSC (3) 8,589.86 45.02 WSW 6,889.31 6800.61 2,711.16 5,739.01 5,948,341.79 313,388.15 0.29 4,466.01 MWD+IFRAK-CAZSC(3) 8,665.37 45.05 305.58 6,956.81 6,868.11 2,750.49 5,793.96 5,946385,44 313,334.18 0.03 4,531.25 MWDAFRAK-CAZ-SC(3) 8,779.86 45.05 306.70 7,023.42 6,934.72 2,789.84 5,847.86 5,948,426.09 313,281.26 0.84 4,595.84 MWD+IFRAKCAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 5,901.48 5,948,467.65 313,228.63 0.31 4,660.97 MWD+IFRAK-CAZSC (3) 8,894.81 45.04 37.55 7,104.76 7,016.06 2,838.87 -3,912.96 5,946476.68 313,217.37 1.49 4,675.01 MNID+IFRAKCAZSC 13) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 5,923.22 5,948,484.85 313,207.30 0.78 4,687.64 MWD+IFRAKCAZSC(4) 9-5/8"X12-1/4" 8,968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 -3,954.29 5,946509.91 313,176.83 0.78 4,726.13 MWD+IFRAKCAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 -3,999.04 5,948,546.27 313,132.96 0.68 4,781.78 MWD+IFR-AKCAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 4,051.36 5,948,588.75 313,081.66 0.66 4,846.82 MWD+IFRAKCAZSC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,989.85 4,103.71 5,948,632.24 313,030.35 1.02 4,912.65 MWD+IFRAK-CAZSC(4) 9,332.26 48.44 311.66 7,411.19 7,322.49 3,034.66 -4,155.97 5,948,678.30 312,979.20 3.40 4,980.43 MWD+IFRAKCAZSC (4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4,210.9 5,946727.23 312,926.26 3.28 5,051.56 MWD+IFRAKCAZSC(4) 9,519.61 54.02 311.03 7528.14 7,439.44 3,130.99 4266.03 5,948,777.27 312,871.52 2.72 5,124.68 MNANFRAK-CAZSC(4) 9,614.22 55.94 310.88 7,682.44 7,493.74 3,181.78 4.324.54 5,946829.46 312,814.26 2.03 5,201.03 MWD+IFRAKCAZSC(4) 9,706.62 59.30 312.69 7,631.91 7,543.21 3,233.78 4,382.70 5,948,882.85 312,757.39 3.99 5,278.11 MWD+IFR.AKCAZSC(4) 8/1572018 5:00:04PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips B ER a UGHES ConoeoPhillips Definitive Survey Report Company: ConocoPhillips(Aleska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project Western North Slope TVD Reference: MT6.05 Actual C 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTS -05 Actual @ 88,70usft (Actual D79) Well: MT6.05 North Reference: True Wellbore: MT645 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EOT 14 Alaska Production Survey MD Inc Azl TVD TVDSS +N/S +E/.W DLS Vertical (uclt) 19 1') (uaR) (uaR) (waft) (MR) Northing Eutlng Prloe•) Section Survey Tool Name Annotation (to (R) IRI 9,801.05 61.09 315.59 7,678.86 7,590.16 3,290.84 -4,441.48 5,948,941.33 312,700.01 3.27 5,359.50 MWD+IFR-AK-CAZSC(4) 9,895.24 63.67 318.04 7,722.52 7,633.82 3,351.70 4,498.56 5,949,003.55 312,644.43 3.68 5,442.75 MWD+IFR-AK-CAZ-SC (4) 9,989.62 65.86 320.87 7,762.77 7,674.07 3,416.57 -4,55404 5.949,069.74 312,590.55 3.57 5,528.08 MWD+1FRJIK-CAZSC(4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 4,607.37 5,949,139.19 312,538.89 3.51 5,614.62 MWD+IFR-AK-CAZSC(4) 10,178.42 71.79 324.53 7,831.43 7,742.73 3,556.72 4,660.08 5,949,212.42 312,487.95 3.78 5,703.71 MWD+IFR-AK-CAZSC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 4,710.97 5,949,286.90 312,438.85 2.18 5,792.64 MWD+IFR-AK-CAZSC(4) 10,366.04 7573 327.31 7,884.53 7,795.83 3,705.72 4,760.88 5,949.363.81 312,390.80 2.91 5,882.86 MWD+IFR-AI(-CAZSC 14) 10,460.54 77.60 329.31 7,906.32 7,817.62 3,783.96 -4,609.18 5,949.443.20 312,344.42 2.86 5,973.99 MWDAFR-AK-CAZBC(4) 10,55635 79.69 330.90 7924.99 7,836.29 3,864.54 4,855.50 5,949.524.87 312,300.07 2.75 6,065.69 MWD+IFR-AK-CAZSC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,607.76 312,257.14 1.90 6,157.48 MW0+IFR-AK-CAZSC(4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949,692.23 312,215.50 2.02 6,249.71 MVA+IFR-AK-CAZSC (4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,986.88 5,949,776.06 312,174.76 1.14 6,340.89 MWDNFR-AK-CAZSC(4) 10,933.50 82.65 332.88 7,977.79 7,889.09 4,195.72 5,030.07 5,949,860.17 312,133.61 0.71 6,432.55 MWD+IFR-AI(-CAZSC(4) 10,977.58 82.88 332.54 7983.26 7,894.56 4,234.59 5,050.12 5,949,899.52 312,114.51 0.77 6,475.33 MWDNFR-AK-CAZSC (4) 7" K 8-314" 11,028.48 82.91 332.15 7,989.56 7,900.86 4,279.33 -5,073.56 5,949,944.81 312092.16 0.77 6.524.80 MWD+IFR-AK-CAZSC(4) 11,106.00 82.89 332.81 7,999.14 7,910.44 4,347.55 5,109.11 5.950,013.87 312,058.29 0.65 6.600.11 MWD4NC ONLY IINC110°)(5) 11,119.05 84.55 331.84 8,000.57 7,911.87 4,359.03 -5,115.13 5,950,025.60 312,052.54 14.71 6,612.81 MWD4NC_ONLY (INC>i0°)(5) 11,212.00 84.82 325.68 8,009.19 7,920.49 4,438.13 5,163.11 5,950,105.73 312,006.50 6.61 6,704.41 MWD -INC ONLY(INC>10°)(5) 11,264.03 85.49 322.23 8,013.58 7,924.88 4,480.04 5,193.61 5,950148.36 311,977.03 6.73 6,756.16 MWD -INC ONLY (INC>101) (5) 11,358.55 89.05 319.48 8,018.09 7,929.39 4,553.24 5.253.20 5,950,222.99 311,919.24 4.76 6,850.55 MWD -INC ONLY (INC>10')(5) 11,453.90 91.38 316.71 8,017.73 7,929.03 4,624.19 -5,316.87 5,950,295.6 311,857.31 3.80 6,945.78 MWD+IFR-AK-CAZSC(6) 11,549.18 91.92 317.12 8,014.99 7,926.29 4,693.75 -5,381.93 5,950,366.57 311,793.97 0.71 7,040.81 MWD+IFRAK-CAZSC(6) 11,644.55 92.44 320.77 8,011.36 7,922.66 4,765.60 -5,444.51 5,950,439.92 311,733.16 3.86 7,136.05 MWD+IFR-AK-CAZSC(6) 11,739.78 93.27 324.15 8,006.61 7,917.91 4,841.01 5,502.45 5.950.516.70 311,677.06 3.65 7,231.11 MWD+IFR-AK-CAZSC(6) 11,834.89 91.02 326.98 8,003.05 7,914.35 4,919.38 5,556.19 5,950,596.36 311,625.25 3.80 7,325.79 MWD+IFR-AK-CAZSC(6) 11,930.25 88.12 330.86 8,003.77 7,915.07 5,001.03 5,605.40 5,950,679.17 311,578.04 5.08 7,420.14 MWD+IFR-AK-CAZSC(6) 12,025.83 89.93 335.47 8,005.39 7,916.69 5,086.27 5,648.53 5,950,765.43 311,537.00 5.18 7,513.43 MWD+IFR-AK-CAZSC(6) 12,121.14 89.99 336.06 8,005.46 7,916.76 5,173.18 5,687.65 5,950,853.26 311,500.00 0.62 7,605.47 MWD+IFR-AK-CAZSC (6) 12,216.12 88.90 338.34 8,006.38 7,917.68 5,260.73 5,724.45 5,950,941.67 311,465.34 2.66 7,696.53 MWD+IFR-AKCAZSC(6) 12,311.41 88.17 338.74 8008.82 7,920.12 5,348.38 -5.759.30 5,951,031.14 311,432.65 0.87 7,787.21 MWD+IFR-AKCAZSC(6) 12,406.40 68.42 337.65 8,011.64 7,922,94 5,437.54 -5,794.57 5,951,120.12 311,399.54 1.18 7,877.77 MWD+IFR-AKCA7-SC(6) TIP from MT6-05PB2 8/15@018 5:00.04PM Page 7 COMPASS 5000 14 Build 85 ConocoPhillipsBAUGHES fid ConocoPhilli � Definitive Survey Report Company: ConoccPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Sib: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usR (Actual Dl 9) Well: MTS -05 North Reference: True Wellbors: MTS -05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey MD Inc AN TVD NDSS •NIS •�-W Map Map DLS Vertical (usR) (% (1) (usR) (usR) (uslt) Wall) Northing Easting (./190') Section Survey Tool Name Annotation (ft) (to (R) 12,501.75 87.61 336.64 8,014.95 7,926.25 5,525.35 5,831.58 5,951,208.79 311,364.67 1.36 7,969.17 MWD+IFR-AI4CAZSC(7) KOP OH ST 12,597.37 89.32 336.18 8,017.51 7,928.81 5,612.94 5,869.83 5,951,297.29 311,328.56 1.85 8,061.19 MWD+IFR-AK-CAZSC(7) 12,691.84 91.56 335.99 8,016.78 7,928.08 5,699.29 -5,908.12 5.951,384.54 311,292.38 2.38 8,152.27 MWD+IFRAK-0AZSC(7) 12,787.01 93.84 339.73 8,012.30 7,923.60 5,787.33 -5,943.95 5,951,473.41 311,268.71 4.60 8,243.08 MWD+IFR-AK-CAZSC(7) 12,882.03 93.14 337.67 8,006.51 7,917.81 5,875.69 5,978.40 5,951,562.57 311,226.42 2.29 8,333.29 MWD+IFRAK-CAZSC(7) 12,977.39 93.40 340.58 8,001.07 7,912.37 5,964.63 5,012.32 5,951,652.31 311194.67 3.06 8,423.61 MWD+IFR-AK-CAZSC (7) 13,073.68 93.46 343.07 7,995.31 7,906.61 6,055.95 5,042.30 5,951,744.32 311,166.92 2.58 8,513.26 MWD+IFR-AK-CAZSC(7) 13,169.11 92.50 343.16 7,990.35 7,901.65 6,147.14 5,069.98 5,951,836.15 311,141.47 1.01 8,601.37 MVA+IFRAKCAZ-SC(7) 13,264.92 93.15 338.84 7,985.63 7,896.93 6,237.60 5,101.12 5,951,927.33 311,112.53 4.55 8,691.10 MWD+IFRAK-CAZSC(7) 13,360.50 93.02 336.30 7,980.48 7,891.78 6,325.81 5,137.54 5,952,016.40 311,078.27 2.66 8,782.43 MWD+IFRAKCAZSC(7) 13,456.13 92.22 334.15 7,976.11 7,887.41 6,412.54 5,177.57 5,952,104.07 311,040.36 2.40 8,874.91 MWD+IFRAKCAZSC(7) 13,550.25 91.67 334.51 7,972.91 7,884.21 6,497.32 5,218.31 5,952,189.81 311,001.69 0.70 8,966.33 MWD+IFRAKCAZSC(7) 13,645.74 91.45 334.28 7,970.31 7,881.61 6,583.40 5,259.57 5,952,276.87 310,962.54 0.33 9,059.07 MWD+IFRAKCAZSC(7) 13,741.36 91.46 333.56 7,967.89 7,879.19 6,669.26 5,301.59 5,952,363.71 310,922.62 0.75 9,152.13 MWD+IFRAKCAZSC(7) 13,837.37 90.71 333.20 7,968.07 7,877.37 6,755.08 5,344.60 5,952,450.54 310,881.70 0.87 9,245.79 MWD+IFRAKCAZSC(7) 13,932.40 90.50 332.78 7,965.07 7,876.37 6,839.74 5,387.75 5,952,536.22 310,840.62 0.49 9,338.64 MWD+IFR-AKCAZSC(7) 14,027.09 95.45 33308 7,960.15 7,871.45 6,923.91 5,430.78 5,952,621.41 310,799.66 5.24 9,431.03 MWD+IFRAKCAZSC(7) 14,122.22 94.96 331.89 7,951.52 7,862.82 7,007.93 5,474.54 5,952,706.46 310,757.95 1.35 9,523.77 MWD+IFRAKCAZSC(7) 14,216.68 93.63 330.77 7,944.45 7,855.75 7,090.67 5,519.73 5,952,790.17 310,714.78 1.84 9.616.35 MWD+IFRAKCAZSC(7) 14,311.72 93.30 330.05 7,938.70 7,850.00 7,173.07 5,566.58 5,952,873.78 310,669.96 0.83 9.709.86 MVA+IFRAKCAZSC(7) 14,407.02 95.13 330.45 7,931.70 7,84300 7,265.68 5,613.74 5,952,957.00 310,624.82 1.97 9,803.58 MWD+IFRAKCAZ-SC(7) 14,503.79 93.54 331.59 7,924.38 7,835.68 7,339.99 5,660.48 5,953,042.92 310,580.14 2.02 9,898.51 MWD+IFRAKCAZSC (7) 14,597.17 93.45 333.24 7,918.69 7,829.99 7,422.60 5,703.64 5,953,126.54 310.539.00 1.77 9,989]8 MWD+IFR-AKCAZ4C(7) 14,692.68 91.45 333.56 7,914.61 7,825.91 7,507.91 5,746.37 5,953,21287 310,498.36 2.12 10,082.86 MVA+IFRAKCAZSC (7) 14.788.05 89.92 333.86 7,913.47 7,824.77 7,593.41 5,788.60 5,953,299.36 310,458.22 1.63 10,175.78 MWD+IFRAK-WSC(7) 14,883.74 87.80 333.46 7,915.37 7,826.67 7,679.14 5,831.05 5,953,386.09 310,417.87 2.25 10,269.01 MWD+IFRAKCAZSC(7) 14,978.03 87.90 332.09 7,918.91 7,830.21 7,762.93 5,874.15 5,953,470.89 310,376.82 1.46 10,361.15 MWD+IFRAKCAZSC(7) 15,074.07 87.96 331.97 7,922.38 7,833.68 7,847.69 5,919.17 5,953,556.72 310,333.88 0.14 10.455.26 MWD+IFRAKCAZ-SC (7) 15,169.08 88.02 331.28 7,925.71 7,837.01 7,931.24 5,964.29 5,953,641.33 310,290.80 0.73 10,548.50 MVA+IFRAKCAZSC (7) 15,263.70 87.89 332.08 7,929.09 7,840.39 8,014.48 -7,009.15 5,953,725.63 310,247.98 0.86 10,641.33 MWD+IFRAKCAZSC(7) 15,358.89 90.09 329.43 7,930.77 7,842.07 8,097.51 -7,055.64 5,953.809.76 310,203.52 3.62 10,735.03 MWD+IFRAKCAZSC(7) 8/15/2018 5: 00:04PM Page 8 COMPASS 5000.14 Build 85 r, ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConcocPhillips(Alaska) Inc, -WNS Local Coordinate Reference: Well MT6-05 Project• Western North Slope TVD Reference: MTS -05 Actual @ 88.70usR (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usR (Actual D19) Well: MT6-05 North Reference: True Wellbore: MTB -05 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EDT 14 Alaska Production Survey a anE 0 Annotation Projection to TD - 4-1/2" x 6" 8/152018 5.00.04PM Page 9 COMPASS 5000.14 Build 85 Vertical MD In AN TVD TVDSS +Nl-S +E/ -W DLS (aaR) (') C) (us*) (11eR) (usfy (usR Northing EMap ell CDLS Section Survey Tool Name IRI ICU 15,464.82 89.92 330.25 7,930.76 7,842.06 8,180.45 -7,103.84 5,953,893.85 310,157.35 0.87 10,829.74 MWD+1FRAK-CAZSC(7) 15,550.30 90.05 331.70 7,930.78 7,842.08 8,263.94 -7,15D.16 5,953,978.43 310,113.07 1.52 10,923.69 MND+IFR-AK-CAZSC(7) 15,645.82 89.98 332.46 7,930.76 7,842.06 8,348.34 -7,194.89 5,954,063.89 310,070.41 0.80 11,017.34 MND+IFR-AK-CAZSC(7) 15,740.85 90.05 333.92 7,930.73 7,842.03 8,433.15 -7,237.75 5,954,149.71 310,029.63 1.54 11,110.12 MWD+IFR-AK-CAZSC(7) 15,836.28 90.82 335.14 7,930.01 7,641.31 8,519.30 -7,278.79 5,954,236.83 309,990.70 1.51 11,202.78 MWD+IFR-AK-0AZSC (7) 15,931.32 95.94 335.38 7,924.41 7,835.71 8,605.44 -7,318.48 5,954,323.90 309,953.11 5.39 11,294.58 MWD+IFR-AK-CAZSC(7) 16,026AD 95.54 335.00 7,914.90 7,825.20 8,691.31 -7,358.18 5,954.41D.70 309,915.52 0.58 11,386.18 MWD+IFR-W-CAZSC(7) 16,122.04 92.86 334.50 7,907.89 7,819.19 8,777.57 -7,398.86 5,954,497.92 309,876.94 2.85 11,478.71 MWD+IFR-AK-CA2SC(7) 16,217.43 93.07 334.33 7.902.96 7,814.26 8,863.49 -7,440.00 5,964,584.81 309,837.90 0.28 11,571.26 MWD+IFR-AK-CAZSC(7) 16,312.20 92.03 333.38 7,898.74 7,810.04 8,948.48 -7,481.72 5,954.670.78 309,798.26 1.49 11,663.45 MND+IFRAK-CAZSC (7) 16,407.71 89.92 332.05 7,897.12 7,808.42 9,033.34 -7,525.49 5,958756.68 309,756.57 2.61 11,766.85 MND+IFR-AK-CAZSC (7) 16,502.31 89.33 332.14 7,897.74 7,809.04 9,116.94 -7,569.76 5,954,841.32 309,714.34 0.63 11,849.58 MWD+IFRAK-CAZSC(7) 16,598.23 89.18 332.24 7,898.98 7,810.28 9,201.78 -7,614.51 5,964.927.21 309,671.67 0.19 11,943.58 MWD+IFRAK-CAZSC(7) 16,693.10 90.20 333.00 7,899.50 7,810.80 9,288.02 -7.658.14 5,955,012.48 309,630.10 1.34 12,036.40 MWD+IFRAK-CAZSC(7) 16,788.77 90.57 332.18 7,898.85 7,810.15 9,370.94 -7,702.18 5,965,098.45 309,588.14 0.94 12,130.02 MWD+IFRAK-CAZSC(7) 16,884.82 91.15 331.27 7,897.41 7,808.71 9,455.52 -7,747.67 5,955,184.10 309,544.72 1.12 12.224.29 MWD+IFRAK-CAZSC(7) 16,980.71 91.18 332.05 7,895.46 7,806.76 9,539.90 -7,793.18 5,955,269.55 309.501.27 0.81 12,318.41 MWD+IFRAK-CAZSC(7) 17,075.73 91.21 332.68 7,893.48 7,804.78 9,624.06 -7,837.24 5,955,354.76 309,459.27 0.66 12,411.45 MND+IFRAK-CAZSC(7) 17,171,05 90.68 333.15 7,891.91 7,803.21 9,708.92 -7,880.64 5,955,440.63 309,417.95 0.74 12,504.60 MWD+IFRAK-CA2SC (7) 17,266.28 91.89 332.62 7,889.77 7,801.07 9,793.66 -7,924.03 5,955,526.40 309,376.63 1.39 12,597.67 MWD+iFR-AK-CAZSC(7) 17,362.98 91.86 332.60 7.886.61 7,797.91 9,879.47 4,966.49 5,955,613.26 309,334.27 0.04 12,692.24 MND+IFRAK-CAZSC (7) 17,391.00 91.86 332.60 7,885.70 7,797.00 9,904.33 -7,981.38 5,955,638.43 309,321.99 0.00 12,719.64 PROJECTED to TD a anE 0 Annotation Projection to TD - 4-1/2" x 6" 8/152018 5.00.04PM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05PB1 50-103-20771-70 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 BA, ICER UGHES a GE company ConocoPhillips Company: ConowPhillips(Alaska) Inc. -WNS Prolaet Western North Slope SIN: GMT1 Lookout Pad Well: MT6-05 Wellbore: MT6-05 Design: MT6-05 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well MT6-05 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Position +WS 0.00 Usti Northing: +El -W 0.00 usft Easling: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MT6-05PB1 Magnetics Model Name Sample Date BGGM2017 5/20/2018 Design MT6-05PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 000 Well MT6-05 MT6-05 Actual Q 88.70usft (Actual D19) MT6-05 Actual @ 88.70usft (Actual Dig) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,543.79usft Latitude: 317,059.98usft Longitude: 0.00usft Ground Level: Declination Dip Angle 1% 1% 16.50 80.72 Tie On Depth: 36.50 +Nl-S +E74W Direction (usft) (usft) 0 0.00 0.00 320.84 8A R gUEGHFS 70° 15' 22.964 N 151' 28'42.930 W 37.20 usft Field Strength (nn 57,422 8/15/2018 4:58:53PM Page 2 COMPASS 5000.14 Build 85 �. ConocoPhillipsER # ConocoPhillips Definitive Survey Report s iic1+E5 Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 TVDSS Project.• Western North Slope TVD Reference: MT6-05 Actual C 88.70usR (Actual D19) DLS Site: GMTl Lookout Pad MD Reference: MT6-05 Actual @ 88.70usR (Actual D19) (usR) Well: MT6-05 North Reference: True Eaeting Wallbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production (R) Survey Program Dab (R) 36.50 0.00 From To 52.20 0.00 Survey Wait) (usR) Survey (Welibora) Tool Name Description Start Date 60.26 263.26 GYD Gyro DMS 16" (MT6-05PB1) GYD-CT-DMS Gyrodele cont.ddllpipe m/s 5/13/2018 296.26 1,957.96 BHGE MWD+IFR+MSA 16"(MT6-05PB1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/15/2018 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-1/4' (MTS -05 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 5/21/2018 8,968.80 11,198.88 BHGE MWD+IFR+MSA Bxe-3/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/4/2018 11,268.35 11,935.87 BHGE MWD+IFR+MSA6"(MT6-05PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/4/2018 Survey MD Inc Azl TVD TVDSS +NAS +E/.W Map Map DLS Vertical (usR) (% (°) (usR) (usm (usR) (uslq Northing Eaeting /100' (" 1 Section Survey Tool Name (R) (RI (R) 36.50 0.00 D.D0 36.50 52.20 0.00 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.26 0.33 231.84 60.26 -28.44 -0.04 -0.05 5,945643.75 317,059.93 1.39 0.00 GYD-CTDMS(1) 161.76 0.36 194.38 161.76 73.06 -0.53 -0.36 5,945,543.27 317,059.61 0.22 -0.18 GYD-CT-DMS(1) 263.26 0.56 211.72 263.25 174.55 -1.25 -0.70 5,945,542.54 317,059.25 0.24 -0.54 GYD-CT-DMS(1) 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,642.22 317,058.96 1.31 -0.62 MM+IFR.AK-CAZSC(2) 390.15 1.24 252.95 390.13 301.43 -2.46 -2.50 5,945,541.40 317,057.42 0.64 432 MWD+IFR.AK-CAZSC(2) 483.51 2.22 291.97 483.44 394.74 -2.08 5.15 5,945,541.84 317,054.79 1.58 1.64 MWD+IFR-AK-CAZSC (2) 577.56 3.84 299.00 577.36 488.66 0.13 5.59 5,945,544.16 317,050.40 1.76 6.16 MWD+IFR-AKCAZSC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 13.43 MWD+IFR-AKCAZSC (2) 766.06 7.00 304.80 764.99 676.29 9.88 54.57 5,945,554.26 317,035.66 1.63 23.17 MWD+IFR-AKCAZSC(2) 860.61 8.03 306.69 858.72 770.02 17.11 54.60 5,945,561.73 317,025.81 1.12 35.11 MWD+IFR-AKCAZSC (2) 955.24 8.96 307.34 952.31 863.61 25.53 -45.76 5,945,570.42 317,014.86 0.99 48.69 MWDNFR-AKCAZSC(2) 1,048.71 10.08 308.87 1.044.50 955.80 35.08 57.91 5,945,58026 317,002.94 1.23 63.77 MWD+IFR-AKCAZSC(2) 1,143.88 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 81.27 MWD+IFR-AKCAZSC(2) 1,238.25 1295 310.96 1,230.19 1,141.49 59.31 57.07 5,945,606.19 316,974.39 1.50 100.97 MWDNFR.AKCAZSC(2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945,620.06 316,957.95 1.25 122.79 MWD+IFR-AK-CAZSC(2) 1,427.45 14.70 308.04 1,413.78 1,325.08 88.66 -122.08 5,945,635.38 316,94D.10 0.89 145.84 MWD+IFR-AKCAZSC (2) 1,521.38 15.39 305.44 1,504.49 1,415.79 103.23 -141.62 5,945,65042 316,920.92 1.03 169.47 MWD+IFR-AKCAZSC(2) 1,616.89 14.91 304.95 1,596.68 1,507.98 117.62 -16202 5,945,665.30 316.9011.88 0.52 193.51 MWD+IFR-AK-CAZSC(2) Survey End Darts 5/13/2018 Annotation 8/152018 4:58:53PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ER ConocoPhilli s"` P Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 ProjxY. Western North Slope TVD Reference: MT6-05 Actual C 88.70usR (Actual D19) Site: GMT7 Lookout Pad MD Reference: MT6-05 Actual C 88.70usft (Actual D19) Well: MT6-05 North Reference: True Waltham: MTS -05 Survey Calculation Method: Minimum Curvature Design: MTS -05 Database: EDT 14 Alaska Production Survey MD Inc AN TVD NDSB +WS +E/ -W Map Map DLS Vertical (usR) (1) 0 (call) lust" (usR) (usR) Northing Easting Section Survey Tool Name (it) (ft) (1/100') (ft) 1,770.53 75.75 305.97 1,687.11 1,598.41 131.71 -181.79 5,945.679.87 316,881.46 0.38 216.93 MWD+IFR-AK-CAZSC(2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202,82 5,945,695.69 316,860.80 1.48 242.08 MWD+IFR-AK-CAZSC(2) 1,899.91 18.01 307.68 1,868.62 1,779.92 163.82 -225.19 5,945,713.02 316,838.85 1.60 269.23 MWDNFR-AK-0AZSC (2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 287.10 MND+IFR-AK-0AZSC (2) 2,014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,810.51 0.83 304.95 MWD+IFR-AK-CAZSC (3) 2.05D.54 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 316.80 MWD+IFR-AK-CAZSC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 329.73 MWD+IFR-AK-CAZSC (3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 501.15 5,945,774.29 316,764.37 2.55 363.28 MWD+IFR-AK-CAZSC(3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 531.10 5,945,798.93 316,735.00 2.78 400.75 MWD+IFR-AKCA7SC(3) 2,372.40 26.72 308.06 2,306.51 2,217.81 272.74 563.43 5,945,825.26 316,703.30 1.60 440.98 MWD+IFR-AK-CAZSC(3) 2,467.33 27.46 308.78 2,391.02 2,302.32 299.60 597.30 5,945,852.94 316,670.10 0.85 483.20 MWD+IFR-AKCAZSC(3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 432.25 5,945,880.75 316,635.82 2.80 526.18 MND+IFR-AKCAZSC(3) 2,651.10 30.86 306.47 2,550.97 2,462.27 354.15 469.44 5,945,909.21 316,599.32 1.14 571.04 MWD+IFR-AKCAZSC(3) 2,744.71 31.74 307.31 2,630.95 2,542.25 383.34 508.33 5.945,939.34 316,561.15 1.05 618.24 MWD+IFR-AKCAZSC(3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 -549.00 5,945,970.76 316,522.23 0.56 666.92 MWD+IFR-AKCAZSC(3) 2,933.95 32.30 307.89 2,791.22 2,702.52 444.83 587.97 5,946,002.74 316,483.03 0.12 716.21 MWDNFR-AKCAZSC (3) 3,028.87 32.99 308.00 2,871.15 2,762.45 476.32 528.35 5,946,035.20 316,443.43 0.73 766.12 MWD+IFR-AKCAZSC(3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.26 5,946,067.97 316,403.28 0.84 816.63 MND+IFR-AKCAZSC(3) 3,217.41 34.79 307.16 3,027.95 2,939.25 540.22 -711.27 5,946,101.03 316,362.09 1.33 868.03 MWD+IFR-AKCAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -764.68 5,946134.96 316,319.49 0.78 920.90 MWD+IFR-AKCAZSC (3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -798.86 5,946169.49 316,276.14 0.79 974.75 MWDNFR-AKCAZSC(3) 3,500.89 36.47 306.40 3,257.86 3,169.16 6,10.06 543,65 5,946,204.11 316,232,18 0.59 1,029.05 MWD+IFR-AKCAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 588.51 5,946,238.62 316,188.14 0.74 1,083.30 MWD+IFRAKCAZSC(3) 3,688.55 37.67 306.99 3,407.60 3,318.90 707.88 534.17 5,946,274.11 316,143.34 0.65 1,138.80 MWD+IFRAKCAZSC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 582.28 5,946309.78 316,096.09 2.97 1,195.94 MWD+IFRAKCAZSC(3) 3,877.30 40,94 303.28 3,552.96 3,464.26 776.44 -1,033.06 5,946,345.04 316,046.14 1.30 1,264.41 MWD+IFRAKCAZSC(3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084.82 5,946380.33 315,995.24 0.08 1,313.49 MWD+IFRAKCAZSC(3) 4,065.45 40.97 303.86 3,695.08 3,606.36 844,47 -1,135.92 5,946,415.55 315,944.98 0.32 1,372.11 MND+IFR-AK-W-SC(3) 4,159.82 42.09 304.09 3,765.71 3,677.01 879.44 -1,187.80 5,946,451.76 315,893,95 1.20 1,431.99 MWD+IFRAKCAZSC(3) 4,254.03 43.41 305.40 3,834.89 3,746.19 915.89 -1,240.34 5,946489.48 315,842.33 1.69 1,493.43 MWD+IFRAKCAZSC(3) 4,345.97 44.99 306.85 3,900.80 3,812.10 963.69 -1,292.10 5,948.528.52 315,791.50 2.04 1,555.42 MWDNFR-AKCAZSC (3) Annotation 133/8" x 16" 8/1512018 4:58.53PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips en ER ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MTS -05 Project: Western North Slope TVD Reference: MT6-06 Actual @ 88.70usR (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70uslt (Actual D19) Well: MT6-05 North Reference: Two Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EDT 14 Alaska Production Survey 8/152018 4:58:53PM Page 5 COMPASS 5000.14 Build 85 Vertical MD Inc Azl TVD TVDSS (4141$ •PJ•W DLS lu•RI I7 l% Neta (USM (41411111)(uelt) Northing Emoting (°1100•) $0C$en Survey Tool Name Annotation (R) IRI IBU 4,444.53 45.64 306.62 3,970.11 3,881.41 995.60 -1,348.26 5,946,571.78 315,736.38 0.68 1,623.38 MWD+IFR-AK-0AZSC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1,037.86 -1,405.45 5,946.615.42 315,680.24 0.22 1,692.27 MWD+IFR-AK-0AZSC (3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,758.31 MWD+IFR-AK-CAZSC(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.65 -1,514.50 5,946,696.82 315,573.15 0.75 1,822.22 MND+IFR-AK-CAZSC(3) 4,624.17 45.60 304.58 4,235.60 4,146.90 1,154.17 -1,588.46 5,946,735.64 315,520.11 0.36 1,885.39 MWD+IFR-AKCAZSC(3) 4,91812 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,906,774.89 315,465.10 0.71 1,950.12 MWD+IFR-AK-CAZSC(3) 5.012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813.73 315,410.16 0.33 2,014.47 MVJD+IFR-AK-CAZSC(3) 5,106.80 45.61 304.63 4,433.20 4,34450 1,267.49 -1,735.77 5,906,852.98 315,355.62 0.42 2,078.91 MNID+IFR-AK-CAZ-SC(3) 5,201.23 45.65 304.35 4.499.23 4,410.53 1,305.71 -1.791.40 5,946,892.54 315,300.93 0.22 2,143.68 MWD+IFR-AK-0AZ-SC(3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,208.4 MND+IFRAK-0AZSC (3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5.946,971.00 315,190.82 0.28 2,273.14 MND+IFRAK-CAZSC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1.958.10 5,947,009.17 315,137.03 0.21 2,336.27 MND+IFRAK-CAZSC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,400.82 MND+IFR-AK-CAZSC (3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,465.02 MWDNFR-AK-CAZSC(3) 5,766.67 45.12 306.17 4,896.71 4,808.01 1,533.8 -2,123.09 5,947,127.89 314,974.88 0.95 2,529.4 MWD+IFRAK-CAZSC(3) 5,861.26 45.08 307.02 4.963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,594.38 MWD+IFR-AKGSSC(3) 5,953.99 45.13 307.58 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,658.25 MWD+IFR-AK-CAZSC(3) 6,048.44 45.04 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,723.35 MND+IFR-AK-CAZSC(3) 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,788.19 MWD+IFRAK-W-SC(3). 6,235.05 45.08 307.01 5,227.45 5,138.75 1,734.21 -2,366.78 5,947,335.35 314,716.18 cm 2,851.91 MWD+IFRAK-CAZSC(3) 6,283.16 45.06 306.90 5,247.31 5,158.61 1,746.18 -2,402.68 5,947.347.70 314,700.57 0.29 2,871.22 MWD+IFR-AK-CAZ-SC(3) GMT1-B1 T2 6,329.17 45.06 306.63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947,376.56 314,663.83 0.29 2,916.54 MWD+IFRAK-CAZSC(3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1,813.94 -2,493.85 5,8.17,417.65 314,611.08 0.16 2,981.34 MWD+IFRAK-CAZSC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2,547.50 5,947,458.46 314,558.40 0.09 3,045.86 MWD+IFRAK-0A7SC(3) 6,612.19 45.05 306.15 5.9316 5,405.06 1,893.01 -2,601.47 5,847,499.31 314,505.41 0.15 3,110.61 MWD+IFRAK-0AZSC(3) 6,706.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3,174.98 MND+IFRAK-CAZSC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3,239.92 MWD+IFRAK-CAZSC(3) 6,896.14 45.10 305.70 5,694.24 5,605.64 2,011.13 -2,764.22 5,947,621.33 314,345.59 0.14 3,304.97 MWD+IFRAK-0A7SC(3) 6,991.21 45.07 305.68 5,761.36 5,672.66 2,050.40 -2,818.90 5,947,661.92 314,291.89 0.03 3,369.96 MWD+IFR-AK-CAZSC(3) 7,085.78 45.08 305.19 5,828.15 5,739.45 2,089.22 -2.873.46 5,947,702.06 314,238.29 0.37 3,434.51 MV4D+IFRAK-CAZSC (3) 7,179.83 45.10 305.01 5,894.55 5,805.85 2,12252 -2.927.95 5,947,741.66 314,184.75 0.14 3,498.62 MWD+IFRAK-CAZSC(3) 8/152018 4:58:53PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report AZI Company: ConowPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MTS -05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: Two Wellbon: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT8-05 Database: EDT 14 Alaska Production Survey MD Inc AZI TVD TVDSS +W.S +E/ -W Map Map DLS Vertical us ( ftl 1% f% IusR) lusft) luslry (uslt) Northing Emoting ("/100') Section Sume Tool Name Y (ft) Iftl (ft) 7,273.52 45.05 304.85 5,960.71 5,872.01 2,165.51 -2,982.33 5,947,780.96 314,131.31 0.13 3,562.41 MWDNFR-AI(-CAZSC(3) 7,368.38 45.09 305.02 6,027.70 5,939.00 2,203.97 5,037.39 5,947,820.74 314,077.21 0.13 3,627.00 MND+IFR-AKCAZSC(3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 -3,091.64 5,947,860.21 314,023.90 0.15 3,690.85 MWDNFR-AKCAZSC(3) 7,565.32 45.01 304.78 6,159.73 6,071.03 2,280.00 5,145.72 5,947,899.37 313,970.76 0.34 3,754.36 MND+IFRAKCAZSC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 3,200.60 5,947.938.63 313,916.82 0.19 3,818.43 MWD+IFRAKCAZSC(3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 5,254.29 5,947,977.43 313,864.06 0.66 3,881.43 MWD+IFRAKCAZSC(3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 -3,308.93 5,946017.84 313,810.38 0.35 3,946.25 MWD+IFRAKCAZSC (3) 7,930]5 45.27 305.88 6,424.41 6,335.71 2,433.69 5,363.13 5,948,058.29 313,757.16 0.05 4,010.82 MWD+IFRAKCAZSC(3) 8,024.98 45.26 306.86 6,490.73 6,402.03 2,473.29 5,417.09 5,948,099.19 313,704.18 0.59 4,075.61 MWD+IFRAKCAZSC(3) 8,118.93 45.30 307.04 6,556.84 6,468.14 2,613.32 5,470.51 5,948,140.50 313,651.75 0.29 4,140.38 MWD+IFRAKCAZSC(3) 8,212.40 45.10 W&W 6,622.70 6,534.00 2,553.17 5,523.53 5,948,181.63 313,599.72 0.27 4,204.76 MWD+IFRAKCAZSC(3) 8,306.99 45.06 305.73 6,689.49 6,600.79 2,593.27 5,577.18 5,946223.01 313,547.06 0.08 4,269.73 MWD+IFRAKCAZ-SC (3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 -3,630.98 5,948,263.96 313,494.25 0.50 4,334.45 MND+IFRAKCAZSC (3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 5,684.69 5,946304.31 313,441.50 0.05 4,398.66 MWD+IFRAKCAZSC(3) 8.589.86 45.02 305.60 6,889.31 6,800.61 2,711.16 5,739.01 5,946344.79 313,388.15 0.29 4,463.33 MWDAFRAKCAZSC(3) 8,685.37 45.05 305.58 6,956.81 6,868.11 2,750.49 5,793.96 5,946385.44 313,334.18 0.03 4,528.53 MND+IFR-AKCAZSC (3) 8,779.66 45.06 306.70 7,023.42 8,934.72 2,789.84 -3,847.86 5.948,426.09 313,281.26 0.84 4.593.08 MWD+IFRAKCAZSC(3) 8,874.41 45.05 307.12 7,090.35 7,001.65 2,830.12 3,901.48 5,948,467.65 313,228.63 0.31 4,658.17 MWD+IFR-AKCAZSC(3) 8,894.81 45.04 307.56 7,104.76 7,016.06 2,838.87 5,912.96 5,946476.68 313,217.37 1.49 4,672.21 MWD+IFRAK-WSC(3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846,79 5,923.22 5,948,484.85 313,207.30 0.78 4,684.83 MWD+IFR-AK-WSC(4) 8,968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 5,954.29 5,948,509.91 313,176.83 0.78 4,723.30 MWD+IFRAKCAZSC(4) 9,049.52 M.64 308.19 7,214.15 7,125.45 2,906.40 5,999,04 5,948,546.27 313,132.96 0.68 4,778.92 MWD+IFRAKCAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 4,051.36 5,948,588.75 313,061.66 0.66 4,843.92 MWD+IFRAKCAZSC(4) 9,238.18 45.65 309.51 7,347.08 7,268.38 2,989.85 4,103.71 5,948,632.24 313,030.35 1.02 4,909.73 MVVD+IFRAKCAZSC(4) 9,332.26 48.44 311.66 7,411.19 7,322,49 3,034.66 4,155.97 5,946.678.30 312,979.20 3.40 4,977.48 MWD+IFR-AK-WSC 14) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4,210,09 5,948,727.23 312,925.26 3.28 5,048.58 MND+IFRAKCAZSC(4) 9,519.61 64.02 311.03 7,528.14 7,439.44 3,130.99 4,266.03 5,948.777.27 312,871.52 2.72 5,121.67 MWD+IFRAKCAZSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5,948,829.46 312,814.26 2.03 5.198.00 MND+IFR-AKCAZ-SC (4) 9,706.62 59.30 312,69 7,631.91 7,543.21 3,233.78 4,382.70 5,948,882.85 312,757.39 3.99 5,275.05 MWD+IFRAKCAZSC(4) 9,801.05 61.09 315.59 7,678.86 7,590.16 3,29D.84 4,"1.48 5,948,941.33 312,700.01 3.27 5,366.41 MWD+IFRAKCAZSC(4) 9,895.24 63.67 318.04 7.722.52 7,633.82 .3,351.70 4,498.56 5,949,003.55 312,644.43 3.58 5,439.65 MWD+IFRAK-WSC(4) Annotation 9-5/8"x 12-1/4" 8/1512018 4.'58:53PM Page 6 COMPASS 5000.14 Build 85 ConocoPhilli P s ConocoPhillips Definitive Survey Report RAEft 0 ' Compatry: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project Western North Slope TVD Reference: MT8-05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usR (Actual DI 9) Wou: MT6-05 North Reference: True Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey MD Inc ANTVD TVDSS +NhB +EJ-w Map Map DSS Vertical (1) (ry C) (loft) (uslt) (1161" lust" Northing Emoting Survey Tool Name Annotation ) (11" (ft) (R) 9,989.62 65.66 320.87 7,762.77 7,674.07 3,416.57 -4554.04 5,949069.74 312,590.55 3.57 5,524.98 MND+IFR-AK-CAZSC(4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 -4,607.37 5,949,139.19 312,538.89 3.51 5,611.52 MWD+IFR-AK-CAZSC(4) 10,178.42 71.79 324.63 7,831.43 7,742.73 3,566.72 4,660.08 5,949,212.42 312,487.95 3.78 5,700.62 MND+IFR-AK-CAZSC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 4.710.97 5,949,286.90 312.438.85 2.18 5,789.57 MWD+IFRAK-CAZSC(4) 10,348.68 75.28 327.05 7,880.18 7,791.48 3,691.60 4,751.78 5,949,349.48 312,399.56 2.91 5,863.10 MWD+IFRAK-CAZSC (4) GMT1-S1 T1 (Copy) 10,366.04 75.73 327.31 7,894.53 7,795.83 3,705.72 4,760.88 5,949,363.81 312,390.80 2.91 5,979.80 MWD+IFRAK-CAZSC (4) 10,460.54 77.60 329.31 7,908.32 7,817.62 3,783.96 4,809.18 5,949,443.20 312,344.42 2.86 5,970.97 MNDNFRAK-CAZSC (4) 10,555.35 79.69 330.90 7,924.99 7,836.29 3,864.64 4,855.50 5,949,524.87 312,300.07 Z75 6,062.70 MWD+IFRAK-CAZSC(4) 10,650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 4,900.44 5,949,607.76 312,257.14 1.90 6,154.53 MWD+IFR-AK-CAZSC(4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 4,944.12 5,949.692.23 312,215.50 2.02 6,246.80 MWD+IFRAKCAZSC (4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 4,986.88 5,949,776.06 312,174.76 1.14 6,338.03 MWD+IFRAK-CAZSC(4) 10,933.50 82.85 332.88 7,977.79 7,889.09 4,195.72 5,03007 5,949.860.17 312,133.61 0.71 6,429.73 MWD+IFRAK-CAZSC(4) 10,977.58 82.88 332.64 7,983.26 7,894.56 4,234.69 -5,05D.12 5,949,899.52 312,114.51 0.77 6,472.53 MWD+IFRAK-CAZSC(4) T'118-3/4" 11,028.48 82.91 332.15 7,989.56 7,900.88 4,279.33 5,073.56 5,949,944.81 312,092.16 0.77 6,522.02 MWD+IFRAK-CAZSC(4) 11,123.21 82.88 332.95 8,001.28 7.912.58 4,362.75 5,116.90 5,950,029.25 312,050.87 0.84 6,614.07 MWD+IFR-AK-CAZSC(4) 11,198.88 82.88 332.19 8,010.66 7,921.95 4,429.39 5,151.49 5,950096.71 312,017.91 1.00 6,687.59 MWDIFRAK-0AZSC(4) 11,268.35 83.00 331.32 8,019.20 7,930.50 4,490.12 5,184.11 5,950,158.21 311,986.77 1.25 6,755.28 MWD+IFRAK-CAZSC(5) 11,36364 82.97 331.64 8,030.83 7,942.13 4,573.22 -5,229.27 5,950,242.38 311,943.65 0.33 6,848.23 MWD+IFRAK-CAZSC (5) 11,459.23 82.96 33249 8,042.54 7,953.84 4,657.04 5,273.71 5,95D,327.25 311,901.26 0.88 6,941.29 MND+IFRAKCAZSC (5) 11,554.02 83.37 332.80 8,053.82 7,965.12 4,740.63 5,316.96 5,960,411.86 311,860.06 0.54 7,033.41 MWD+IFR-AK-GAZSC (5) 11,648.96 87.24 333.40 8061.59 7,972.89 4,825.00 5,359.76 5,950,497.23 311,819.32 4.12 7,125.86 MWD+IFRAKCAZSC(5) 11,744.77 92.76 337.30 8.061.59 7,972.89 4,912.03 -5,399.70 5,950,685.20 311,781.51 7.05 7,218.56 MND+IFRAKCAZSC (5) 11,840.18 93.46 335.49 8,056.42 7,967.72 4,999.32 5,437.84 5,950,673.39 311,745.50 2.03 7,310.33 MWD+IFRAKCAZSC(5) 11,935.87 93.52 334.32 8,050.59 7,961.89 5,085.82 5,478.35 5,950,760.84 311,707.10 1.22 7,402.98 MWD+IFRAKCAZSC(5) 12,037.OD 93.52 334.32 8,044.38 7,955.68 5,176.78 5,522.09 5,950,852.84 311,665.59 0.00 7,501.14 PROJECTED to TO 4.1/2"K6" 8/152018 4:58:53PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhiIli ps(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-05PB2 50-103-20771-71 Baker Hughes INTEQ Definitive Survey Report 15 August, 2018 BA ER F�UGHES a GE company 8/15/2018 4:59:36PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BAER 0 UGHES ConocoPhilh S 1't t i� Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -NMS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual @ 88.70usft (Actual Dl 9) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska 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) Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-05 Well Position •N/S 0.00 usft Northing: 5,945,543.79usft Latitude: 70' 15'22.964 N +E/ -W 0.00 usft Easting: 317,059.98usft Longitude: 151°28'42.930W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00usft Ground Level: 37.20 usft Wellbore MT6-05PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) 0 (nT) BGGM2017 5/20/2018 16.50 80.72 57,422 Design MT6-05PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,028.48 Vertical Section: Depth From (TVD) .N/S •E1 -W Direction (usft) (usft) (usft) (•) 0.00 0.00 0.00 316.54 8/15/2018 4:59:36PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ER ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-05 Map Wellbore: MT6-05 MD Design: MT6-05 TVD Survey Program +WS Date From To DLS (usft) (usfo Survy(Wellbore) 60.26 263.26 GYD Gyro OMS 16" (MT6-05PB1) 29626 1,957.96 BHGE MWD+IFR+MSA 16"(MT6-05PB1 2,050.54 8,894.81 BHGE MWD+IFR+MSA 12-116' (MT6-05 8,968.80 11,028.48 BHGE MWD+IFR+MSA 6X8.314"(MTS-0 11,106.00 11,358.55 BHGE MWD INC 6"(MT6-05PB2) 11,453.90 13,740.32 BHGE MWD+IFR+MSA 6"(MTB-05PB2) Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Toof Name GYDCT-DMS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD -INC -ONLY (INC>10') MWD+IFR-AK-CAZ-SC Well MT6-05 MT6-05 Actual G 88.70usft (Actual 019) MTS -05 Actual C 88.70usft (Actual Of 9) True Minimum Curvature EDT 14 Alaska Production Description Gymdata cont.drillpipe mis MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD-INC_ONLY_FILLER (INC -10-) MWD+IFR AK CAZ SCC Survey Start Date 5/13/2018 5/15/2018 5/21/2018 6/4/2018 6/22/2018 6/22/2018 Survey End Date 5/13/2018 Map Map Vertical MD Inc Ail TVD TVDSS +WS +E/ -W DLS (usfo (1) (') (usfo NOR) (usfo (usR) Northing Easting ('/700') Section Survey Tool Name {1nROt8tlOn (g) (� (ti) 36.50 0.00 0.00 36.50 52.20 0.0D 0.00 5,945,543.79 317,059.98 0.00 0.00 UNDEFINED 60.26 0.33 231.84 6D.26 -28.44 -0.04 -0.05 5,945,543.75 317,059.93 1.39 0.01 GYDCT-DMS(1) 161.76 0.38 194.38 161.76 73.06 -0.53 4.36 5,945,543.27 317,059.61 0.22 -0.14 GYDCT-0M8(1) 263.26 0.56 211.72 263.25 174.55 4.26 -0.70 5,945,542.54 317,059.25 0.24 -0.43 GYDCT-0MS(1) 296.26 0.96 224.50 296.25 207.55 -1.60 -0.98 5,945,542.22 317,058.96 1.31 -0.49 MWD-IFR-AK-CAZ-SC (2) 39D.15 1.24 252.95 390.13 301.43 -2.46 -2.60 5,9!5,541.40 317,057.42 0.64 -0.D6 MWD+IFR-AKCAZSC(2) 483.51 2.22 291.97 483.44 394.74 -2.06 5.15 5,945,541.84 317,054.79 1.58 2.03 MWD+IFR-AKCAZSC(2) 577.56 3.84 299.00 577.36 488.66 0.13 -9.59 5,945,544.16 317,050.40 1.76 6.69 MWD+IFR-AKCAZ-SC(2) 672.51 5.48 303.35 671.99 583.29 4.17 -16.16 5,945,548.35 317,043.93 1.77 14.14 MWD+IFRAKCAZSC(2) 766.08 7,00 304.80 764.99 676.29 9.88 -24.57 5,945,554.26 317,035.66 1.63 24.07 MWD♦IFRAK-CAZ.SC(2) 860.61 8.03 306.69 858.72 770.02 17.11 -34.60 5,945,561.73 317,025.81 1.12 36.22 MWD+IFRAK-CAZSC(2) 955.24 8.96 307.34 952.31 863.61 25.53 -45.76 5,945,570.42 317,014.68 0.99 50.00 MVVD+IFRAKCAZSC (2) 1,048.71 10.08 308.87 1,044.50 955.80 35.08 57.91 5,945,58026 317,002.94 1.23 65.30 MWD+IFRAKCAZSC(2) 1,143.88 11.57 309.42 1,137.97 1,049.27 46.36 -71.77 5,945,591.88 316,989.36 1.57 83.02 MWD+IFRAKCAZSC(2) 1,238.25 12.95 310.96 1,230.19 1,141.49 59.31 S7.07 5,945,605.19 316,974.39 1.50 102.94 MWD+IFRAKCAZSC(2) 1,332.92 14.13 310.53 1,322.22 1,233.52 73.77 -103.86 5,945,620.06 316,957.95 1.25 124.99 MWD+IFRAK-WSC(2) 1,427.45 14.70 308.04 1,413.78 1,325.08 88.66 -122.08 5,945,635.38 316,940.10 0.89 148.33 MWD+IFRAKCAZSC(2) 1,521.38 15.39 305.44 1,504.49 1 415.79 103.23 -141.62 5,945,65042 316,920.92 1.03 172.34 MWD+IFR-AK-CAZSC (2) 8/152018 4: 59 36P Page 3 COMPASS 5000.14 Build 85 survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Coordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70usft (Actual D79) Well: MT6-05 North Reference: True Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MTe-05 Database: EDT 14 Alaska Production survey lm � 0 8/1512018 4:59:36PU Page 4 COMPASS 5000.14 Build 85 Map Map vertical MD Inc AN TVD TVDBS +W$ +E/.W DLS Walk) r Northing Emoting (.110w) See6on guvy Tool NamAnnotationII (11" (R) 1,616.89 14.91 304.96 1,5%.68 1,507.98 117.62 -162.02 5,945,665.30 316,900.88 0.62 196.82 MWD+IFR-AK-CAZSC(2) 1,710.53 15.15 305.97 1,687.11 1,598.41 131.71 -181.79 5,945,679.87 316,881.46 0.38 220.65 MWD+IFR-AK-CAZSC(2) 1,805.77 16.56 306.15 1,778.73 1,690.03 147.03 -202.82 5,948695.69 316,860.80 1.48 246.23 MWD+IFR-AK-CAZSC(2) 1,8%.91 18.01 37.58 1,868.62 1,779.92 163.82 -225.19 5,948713.02 316,838.85 1.60 273.81 MWD+IFR-AK-CAZSC(2) 1,957.96 18.83 308.11 1,923.69 1,834.99 175.07 -239.68 5,945,724.62 316,824.64 1.44 291.94 MWDNFR-AWCAZSC(2) 2,014.00 19.29 307.93 1,976.66 1,887.96 186.34 -254.09 5,945,736.24 316,810.51 0.83 310.04 MWD+IFR-AK-0AZSC(3) 13.318'%1W 2,050.64 19.59 307.82 2,011.12 1,922.42 193.81 -263.69 5,945,743.94 316,801.09 0.83 322.06 MWD+IFR-AK-CAZ-SC(3) 2,089.52 20.21 307.93 2,047.77 1,959.07 201.96 -274.16 5,945,752.33 316,790.82 1.59 335.18 MWD+IFRAK-CAZSC(3) 2,183.73 22.60 308.62 2,135.47 2,046.77 223.26 501.15 5,945,774.29 316,764.37 2.55 369.20 MND+IFRAK-CAZSC (3) 2,278.30 25.23 308.60 2,221.92 2,133.22 247.18 531.10 5,945,798.93 316,735.00 2.78 407.17 MWD+IFRAK-CAZSC(3) 2,372.40 26.72 308.06 2,308.51 2,217.81 272.74 563.43 5,945,825.26 316,703.30 1.60 447.96 MWD+IFRAK-CAZSC(3) 2,467.33 27.46 308.78 2,391.02 2,37.32 299.60 597.30 5,948852.94 316,670.10 0.85 490.75 MWD+IFRAK-CAZSC(3) 2,559.45 29.82 306.63 2,471.87 2,383.17 326.58 -032.25 5,945,880.75 316,635.82 2.80 534.37 MWD+IFRAK-CAZSC 13) 2,651.10 30.86 306,47 2,550.97 2,462.27 364.15 469.44 5.945,909.21 316,599.32 1.14 579.96 MWD+IFRAK-CAZSC(3) 2,744.71 31.74 37.31 2,630.95 2,542.25 383.34 50633 5,945,939.34 316,561.15 1.05 627.90 MWD+IFRAK-CAZSC(3) 2,839.16 32.22 307.74 2,711.07 2,622.37 413.81 548.00 5,945,970.76 316,522.23 0.56 677.31 MWD+IFRAK-CAZSC(3) 2,933.95 32.30 307.89 2,791.22 2,77.52 444.83 587.97 5,946,07.74 316,483.03 0.12 727.32 MND+IFRAK-CAZSC (3) 3,78.87 32.99 308.00 2,871.15 2,782.45 476.32 528.35 5,946,035.20 316,443.43 0.73 777.94 MND+IFRAK-CAZSC (3) 3,123.33 33.57 307.67 2,950.12 2,861.42 508.11 569.28 5,946067.97 316,403.28 0.64 829.18 MWD+IFRAK-CAZSC(3) 3,217.41 34.79 307.16 3,027.95 2,939.25 640,22 -711.27 5,946,101.09 316,362.09 1.33 881.36 MWD+IFRAK-CAZSC(3) 3,311.94 35.52 307.03 3,105.23 3,016.53 573.05 -754.68 5,946,134.96 316,319.49 0.78 935.05 MWD+IFRAK-CAZSC(3) 3,406.49 36.25 307.26 3,181.84 3,093.14 606.51 -7%.% 5,946.169.49 316,276.14 0.79 989.73 MNDNFR-AK-CAZSC(3) 3,500.89 36.47 306.40 3,257.86 3,169.16 640.06 543,65 5,946,204.11 316,232.18 0.59 1,044.89 MWD+IFRAK-CAZSC(3) 3,594.37 37.06 306.99 3,332.75 3,244.05 673.49 588.51 5,946,238.62 316,188.14 0.74 1,100.02 MND+IFRAK-CAZSC(3) 3,688.55 37.67 306.99 3,47.60 3,318.90 707.88 534.17 5,946,274.11 316,143.34 0.65 - 1,156.39 MM+IFRAK-CAZ-SC(3) 3,783.05 39.95 304.39 3,481.23 3,392.53 742.40 582.28 5,946,309.78 316,096.09 2.97 1,214.53 MWD+IFRAK-CAZSC(3) 3,877.30 40.94 303.28 3,552.96 3,464.26 776.4 -1,033.06 5,946345.04 316,046.14 1.30 1274.17 MWD+IFR-AK-CAZSC(3) 3,971.83 40.95 303.40 3,624.36 3,535.66 810.49 -1,084.7 5,946,380.33 315,9%.24 0.08 1,334.48 MND+IFRAK-CAZSC(3) 4,065.45 40.97 303.86 3,695.06 3,606.36 844.47 -1,135.92 5,946,415.55 315,944.98 0.32 1,394.30 MWD+IFRAK-CAZSC(3) 4,159.82 42.09 304.09 3,765.71 3,67701 879.44 -1,18780 5,946451.76 315,893.96 1.20 1,455.37 MWD+IFRAK-CAZSC(3) 4,254.03 43.41 305.40 3,834.89 3,746.19 915.89 -1,240.34 5,946,489.48 315,842.33 1.69 1,517.97 MWD+IFRAK-CAZSC(3) lm � 0 8/1512018 4:59:36PU Page 4 COMPASS 5000.14 Build 85 Survey MD ConocoPhillips Azl ConocoPhillips Definitive Survey Report +WS Company: Con=Phillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MT6-05 Actual Q 88.70usR (Actual of 9) Site: GMT1 Lookout Pad MD Reference: MT6-05 Actual @ 88.70us8 (Actual Of 9) Well: MT6-05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey MD Inc Azl N D TVDgB +WS +EJ.W Map Map DLS Vertical (uatt) (% (% (watt) (-ft) (uaft) (Wft) Northing Easting (°1100•) Section Survey Tool Name (ft) (ft) (ft) 4,345.97 44.99 306.85 3,900.80 3,812.10 953.69 -1,292.10 5,948,528.52 315,791.50 2.04 1,581.01 MWD+IFR-AK-0AZSC(3) 4.W53 45.64 306.62 3,970.11 3,881.41 995.60 -0,348.26 5,946,571.78 315,736.38 0.68 1,650.06 MWD+IFR-AK-0AZSC(3) 4,544.01 45.62 306.31 4,039.67 3,950.97 1037.86 -1,405.45 5,946,615.42 315,680.24 0.22 1,720.07 MWD+IFRAKCAZSC (3) 4,639.51 45.64 306.01 4,106.46 4,017.76 1,078.14 -1,460.57 5,946,657.02 315,626.12 0.23 1,767.22 MNAHFR-AK-CAZSC(3) 4,732.20 45.63 305.04 4,171.27 4,082.57 1,116.66 -1514.5D 5,946,696.82 315,573.15 0.75 1,852.27 MND+IFR-AKCAZSC(3) 4,824.17 45.60 304.58 4,23660 4,146.90 1,154.17 -1,568.46 5,946,735.64 315,520.11 0.36 1,916.62 MWD+IFR-AKCAZSC(3) 4,918.72 45.66 303.65 4,301.72 4,213.02 1,192.07 -1,624.42 5,948,774.89 315,465.10 0.71 1,982.62 MWD+IFR-AKCAZSC(3) 5,012.80 45.66 304.08 4,367.47 4,278.77 1,229.57 -1,680.29 5,946,813.73 315,410.16 0.33 2.048.27 MWD+IFR-AKCAZSC(3) 5,106.80 45.61 304.63 4,433.20 4,344.50 1,267.49 -1,735.77 5,946.862.98 315,355.62 0.42 2,113.96 MWD+IFR-AKCAZSC(3) 5,201.23 45.65 304.35 4,499.23 4,410.53 1,305.71 -1,791.40 5,946,892.54 315,300.93 0.22 2,179.97 MWD+IFRAKCAZSC(3) 5,295.79 45.60 304.06 4,565.36 4,476.66 1,343.71 -1,847.30 5,946,931.88 315,245.97 0.23 2,246.00 MND+IFRAKCAZSC (3) 5,390.61 45.38 303.84 4,631.84 4,543.14 1,381.47 -1,903.39 5,946,971.00 315,190.82 0.28 2,311.99 MWD+IFR-AKCAZSC(3) 5,483.33 45.32 304.10 4,697.00 4,608.30 1,418.33 -1,958.10 5,947,009.17 315,137.03 0.21 2,376.37 MWD+IFRAK-W-SC(3) 5,578.13 45.23 304.42 4,763.71 4,675.01 1,456.25 -2,013.77 5,947,048.42 315,082.30 0.26 2,442.19 MWD+IFR-AKCAZSC(3) 5,672.39 45.10 304.91 4,830.17 4,741.47 1,494.26 -2,068.74 5,947,087.76 315,028.27 0.39 2,507.60 MND+IFRAKCAZSC(3) 5,766.67 45.12 306.17 4,896.71 4,808.01 1,533.09 -2,123.09 5,947.127.89 314,974.88 0.95 2,573.16 MWD+IFRAKCAZSC(3) 5,861.26 45.08 307.02 4,963.48 4,874.78 1,573.03 -2,176.88 5,947,169.13 314,922.08 0.64 2,639.16 MND+IFRAKCA7-SC(3) 5,963.99 45.13 307.58 5,028.93 4,940.23 1,612.84 -2,229.14 5,947,210.19 314,870.81 0.43 2,703.99 MND+IFRAKCAZSC (3) 6,048.44 45.04 307.59 5,095.61 5,006.91 1,653.63 -2,282.14 5,947,252.26 314,818.82 0.10 2,770.06 MWD+IFRAKCAZSC (3) 6,142.51 45.05 307.90 5,162.08 5,073.38 1,694.38 -2,334.78 5,947,294.27 314,767.19 0.23 2,835.85 MWD+IFRAKCAZSC(3) 6,235.05 45.06 307.01 5,22245 5,138.75 1,734.21 -2,386.78 5,947,335.35 314,716.18 0.68 2,900.53 MWD+IFR-AKCAZSC(3) 6,329.17 45.06 306.63 5,293.94 5,205.24 1,774.14 -2,440.11 5,947.376.58 314,663.83 0.29 2,966.19 MWD+IFRAKCAZSC (3) 6,423.63 45.08 306.42 5,360.65 5,271.95 1,813.94 -2,493.85 5,947,417.65 314,611.08 0.16 3,032.05 MND+IFRAKCAZSC(3) 6,517.70 45.12 306.32 5,427.05 5,338.35 1,853.46 -2.597.50 5,947,458.46 314,658.0 0.09 3,097.64 MND+IFRAKCAZ-SC(3) 6,612.19 45.05 306.15 5,493.76 5,405.06 1,893.01 -2,601.47 5,947,499.31 314,505.41 0.15 3,163.47 MND+IFRAKCA7SC(3) 6,708.20 45.08 306.10 5,560.16 5,471.46 1,932.24 -2,655.23 5,947,539.83 314,452.63 0.05 3,228.92 MWD+IFR.4KCA7-SC(3) 6,801.05 45.11 305.89 5,627.12 5,538.42 1,971.73 -2,709.58 5,947,580.62 314,399.25 0.16 3,294.97 MWD+IFRAKCAZSC(3) 6,896.14 45.10 305.70 5,694.24 5,605.54 2,011.13 -2,764.22 5,947,621.33 314.345.59 0.14 3,361.15 MWD+IFR-AKCAZSC(3) 6.991.21 45.07 305.68 5,761.36 5,672.66 2,050.40 .2,818.90 5,947,661.92 314,291.89 0.03 3,427.27 MWD+IFRAKCAZSC(3) 7,085.78 45.08 305.19 5,828.15 5,739.45 2,089.22 -2,873.6 5,947,702.06 314,238.29 0.37 3,492.97 MWD+IFRAKCAZSC(3) 7,179.83 45.10 305.01 5,894.55 5,805.85 2.127.52 -2,927.95 5,947,741.66 314,184.75 0.14 3,558.26 MWD+IFRAK-CAZSC(3) Annotation BATE 8/152018 4:59 36P Page 5 COMPASS 5000.14 Build 85 Survey ConocoPhillips BTER es ConocoPhillips Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -NMS Local Coordinate Reference: Well MT6-05 Project, Western North Slope TVD Reference: MTS -05 Actual C 88.70usft (Actual Dl 9) Site: GMT1 Lockout Pad MD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Well: MTB -05 North Reference: True Wellbore: MT6-05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey 81152018 4:59:36PM Page 6 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AZI TVD TVDSS +W3 +E/ -W DLS (usfl) (') (') Wel" (uslt) (usft) (usft) Northing Easting Section Survey Tool Nam Annotation (R) (RI (R) 7,273.52 45.05 304.86 5,980.71 5,872.01 2,165.51 -2,98233 5,947,78D.96 314,131.31 0.73 3,623.24 MWD+IFR-AI(-CAZSC (3) 7,358.38 45.09 305.02 6,027.70 5,939.00 2,203.97 5,037.39 5,947,820.74 314,077.21 0.13 3,689.02 MWD+IFR-AK-CAZSC (3) 7,462.04 45.09 305.22 6,093.82 6,005.12 2,242.13 5,091.64 5,947860.21 314,023.90 0.15 3,754.04 MWD+IFR-AK-CAZSC(3) 7,555.32 45.01 304.78 6,159.73 6,071.03 2,280.00 5,145.72 5,947,899.37 313.970.76 0.34 3,818.72 MWD+IFR-AI(-CAZSC(3) 7,649.62 45.05 304.53 6,226.37 6,137.67 2,317.94 5,200.60 5,947,938.63 313,916.82 0.19 3,884.01 MWD+IFR-AK-CAZSC(3) 7,742.03 45.23 305.35 6,291.56 6,202.86 2,355.45 -3,254.29 5,947,977.43 313,864.06 0.66 3,948.17 MWD+IFR-AK-CA7SC(3) 7,836.64 45.26 305.81 6,358.17 6,269.47 2,394.54 5,308.93 5,946017.84 313,810.38 0.35 4,014.13 MWD+IFR-AK-CAZSC(3) 7,930.75 45.27 305.88 6,424.41 6,335.71 2,433.69 -3,363.13 5,948,058.29 313,757.16 0.05 4,079.82 MWD+IFR-AK-CAZSC (3) 8,024.98 45.26. 306.66 6,490.73 6,402.03 2,473.29 -3,417.09 5,948,099.19 313,704.18 0.59 4,145.69 MWD+IFR-AK-CAZSC(3) 8,118.93 45.30 307.04 6,556.84 6468.14 2,513.32 -3,470.51 5.946140.50 313.651.75 0.29 4,211.49 MVA+IFRAK-CAZSC(3) 8,212.40 45.10 306.82 6,622.70 6,534.00 2,553.17 5,523.53 5,948,181.63 313,599.72 0.27 4,276.89 MWD+IFR-AK-0AZSC(3) 8,306.99 45.06 306.73 6.689.49 6,600.79 2,593.27 5,577.18 5,948,223.01 313,547.06 0.08 4,342.89 MWD+IFR-AK-CAZSC(3) 8,401.40 45.07 306.06 6,756.17 6,667.47 2,632.93 5,630.98 5.948,263.96 313,494.25 0.50 4,408.68 MVA+IFR-AK-0AZ-SC (3) 8,495.22 45.06 305.99 6,822.44 6,733.74 2,671.99 5,684.69 5,948,304.31 313,441.60 0.05 4,473.98 MVA44FR-AK-CAZSC (3) 8,589.86 4602 305.60 6,889.31 6,800.61 2,711.16 5,739.01 5,948,344.79 313,388.15 0.29 4,539.78 MWD+IFR-AK-CAZ-SC (3) 8,685.37 45.05 305.58 6,956.81 6868.11 2,750.49 5,793.96 5,948985.44 313,334.18 0.03 4,606.12 MVA+IFR-AK-CAZSC(3) 8,779.66 45.08 306.70 7,023.42 6.934.72 2,789.84 5,847.86 5,948,426.09 313,281.26 0.84 4,671.76 MWD+IFR-AK-CAZSC(3) 8,87441 45.05 307.12 7,090.35 7,001.65 2,830.12 5.901.48 5.W8q 7.65 313,228.63 0.31 4,737.88 MWD+IFR-AK-0AZSC(3) 8,894.81 45.04 307.55 7,104.76 7,016.06 2,838.87 5,912.96 5,948.476.68 313,217.37 1.49 4,752.13 MWD+IFR-AK-CAZSC(3) 8,913.12 45.07 307.75 7,117.70 7,029.00 2,846.79 5,923.22 5,948,484.85 313,207.30 0.78 4,764.93 MVA+IFR-AI(-CAZSC (4) 9-5/8" z 12-1/4" 6968.80 45.18 308.34 7,156.98 7,068.28 2,871.11 5,954.29 5,948.509.91 313,176.83 0.78 4,803.96 MWD+IFR-AK-CAZSC(4) 9,049.52 44.64 308.19 7,214.15 7,125.45 2,906.40 5,999.04 5.948.546.27 313,132.96 0.68 4,860.35 MWDAFR--CAZSC(4) 9,143.80 45.26 308.27 7,280.87 7,192.17 2,947.62 4,051.36 5,948.588.75 313,081.66 0.66 4,926.26 MWD+IFR-AK-CAZSC(4) 9,238.18 45.65 309.51 7,347.08 7,258.38 2,989.85 4,103.71 5,948,632.24 313,030.35 1.02 4.992.92 MWD+IFR-AK-CAZSC(4) 9,332.26 48.44 311.66 7,411.19 7,322.49 3,034.66 4,155.97 5,948,678.30 312,979.20 3.40 5,061.40 MWD+IFR-AK-CAZSC(4) 9,426.43 51.49 311.06 7,471.75 7,383.05 3,082.29 4,210.09 5,948,727.23 312.926.26 3.28 5,133.19 MWD+IFR-AK-CMSC(4) 9,519.61 54.02 311.03 7,528.14 7,439.44 3,130.99 4,266.03 5,948.777.27 312,871.52 2.72 5,207.02 MWD+IFR-AK-CAZSC(4) 9,614.22 55.94 310.88 7,582.44 7,493.74 3,181.78 4,324.54 5.948,829.46 312,814.26 2.03 5,284.13 MWDNFR-AK-CAZSC(4) 9,706.62 59.30 312.69 7,631.91 7,543.21 3,233.78 4,382.70 5.948,882.85 312,757.39 3.99 5,361.88 MWD+IFR-AK-CAZSC(4) 6801.05 61.09 315.59 7,678.86 7,590.16 3,290.84 4,441.48 5,948,941.33 312.700.01 3.27 5,443.74 MWD+IFR-AK-CAZSC(4) 9,895.24 63.67 318.04 7,722.52 7.633.82 3,351.70 4,498.56 5,949,003.55 312,644.43 3.58 5,527.17 MWD+IFR-AK-CAZSC(4) 81152018 4:59:36PM Page 6 COMPASS 5000.14 Build 85 Survey ConocoPhillips ERES $ ConocoPhillips Definitive Survey Report Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project Western North Slope TVD Reference: MTB -05 Actual 88.70usft (Actual D19) Site: GMT7 Lookout Pad MD Reference: MT8-05 Actual 88.70usft (Actual D19) Well: MT6.05 North Reference: True Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MT6.05 Database: EDT 14 Alaska Production Survey Map Vertical MD Inc Azl TVD 7VDSS +111-S +E/ -W Northing Eluding DLS Saegen Survey Tool Name Annotation (usft) 0 r) (tag) Wait) (usft) (usft) (it) (ft) (1111001 (ft) 9,989.62 65.86 320.87 7,762.77 7,674.07 3,416.57 1,554.04 5,949,069.74 312,590.55 3.57 5,612.42 MND+11FR-AK-CAZSC (4) 10,083.55 68.49 323.03 7,799.20 7,710.50 3,484.75 1,607.37 5,949,139.19 312,538.89 3.51 5,698.59 MWD+IFR-AK-CAZSC(4) 10,178.42 71.79 324.53 7,831.43 7,742.73 3,566.72 1,660.08 5,949,212.42 312,487.95 3.78 5,787.09 MWD+IFRAKCAZSC(4) 10,271.93 73.35 325.90 7,859.44 7,770.74 3,630.00 1,710.97 5,949,286.90 312,438.85 2.18 5,875.28 MWD+IFR-AK-CAZSC (4) 10,366.04 75.73 327.31 7,884.53 7,796.83 3,705.72 1,760.88 5,949,363.81 312,390.80 2.91 5,964.58 MND+IFRAK-CAZSC(4) 10,460.54 77.60 329.31 7,905.32 7,817.62 3,783.96 1,809.18 5,949,443.20 312,344.42 2.85 6,054.59 MND+IFRAK-CAZSC (4) 10,555.35 79.69 330.90 7,924.99 7,836.29 3,884.54 1,855.50 5,949,524.87 312,300.07 2.75 6,144.99 MND+IFRAK-CAZSC(4) 10.650.00 81.37 331.55 7,940.56 7,851.86 3,946.37 1,900.44 5,949,607.76 312,257.14 1.90 6,235.25 MWD+IFRAK-CAZ-SC (4) 10,745.13 82.41 333.18 7,953.98 7,865.28 4,029.80 1,944.12 5,949,692.23 312,215.50 2.02 6,325.85 MND+IFRAK-CAZSC(4) 10,839.12 82.85 332.20 7,966.04 7,877.34 4,112.62 1,986.88 5,949,776.06 312,174.76 1.14 6,415.38 MND+IFRAK-CAZ-SC(4) 10,933.50 82.85 332.88 7,977.79 7,889.09 4,195.72 5,030.07 5,999,860.17 312,133.61 0.71 6,505.40 MND+IFRAK-CAZSC(4) 10,977.58 82.88 332.54 7,983.26 7,894.56 4,234.59 5,050.12 5,949,899.52 312,114.51 0.77 6,547.41 MWD+IFR-AK-CAZSC(4) 7"X8-314" 11,028.48 82.91 332.15 7,989.56 7,900.86 4,279.33 5,073.56 5,949,944.81 312,092.16 0.77 6,596.01 MN4D+IFRAK-CAZSC (4) TIP 11,106.00 a2.89 332.81 7,999.14 7,910.44 4.347.55 5,109.11 5,950,013.87 312,058.29 0.85 6,669.98 MWD -INC _ONLY (INC>10')(5) KOP-TOWS 11,119.05 84.55 331.84 8,000.57 7,911.87 4,35903 5,115.13 5,950,025.50 312,052.54 14.71 6,682.46 MND -INC ONLY(INC>10')(5) Inteprolated Azimuth 11,212.00 84.82 325.68 8,09.19 7,920.49 4,438.13 5,163.11 5,950,106.73 312.006.50 6.61 6.772.87 MWD -INC ONLY(INC>10°)(5) Inteprolated Azimuth 11,264.03 85.49 322.23 8.013.58 7,924.88 4,480.04 5,193.61 5,950,148.36 311,977.03 6.73 6824.27 MWD-INC_ONLY (INC>10°)(5) Inteprolated Azimuth 11,358.55 89.05 319.48 8,018.9 7,929.39 4,553.24 5,253.20 5,950,222.99 311,919.24 4.76 6,918.39 MWD4NC ONLY(INC>10°)(5) Inaprolated Azimuth 11,453.90 91.38 316.71 8,017.73 7,929.03 4,624.19 5,316.87 5,950,295.46 311.857.31 3.80 7,013.69 MWD+IFR-AK-CAZSC(6) 11,549.18 91.92 317.12 8,014.99 7,926.29 4,693.75 5,381.93 5,950,386.57 311,793.97 0.71 7,108.93 MWD+IFRAK-CAZSC(6) 11,644.55 92.44 320.77 8,011.36 7,922.66 4,765.60 5,444.51 5,950439.92 311,733.16 3.86 7,204.13 MWD+IFR-AK-CAZSC(6) 11,739.78 93.27 324.15 8,006.61 7,917.91 4,641.01 5,602.45 5,950,516.70 311,677.06 3.65 7,298.72 MND+IFRAK-CAZSC(6) 11,834.89 91.02 326.98 8,003.06 7,914.35 4,919.38 -5,556.19 5,906,596.36 311,625.25 3.80 7,392.57 MWD+IFR-AK-CAZSC(6) 11,930.25 88.12 330.86 8,09.77 7,915.07 5,001.9 -5,605.40 5,950,679.17 311,578.04 5.08 7,485.68 MWD+IFRAK-CAZSC(6) 12,025.83 89.93 335.47 8,005.39 7,916.69 5,086.27 5,648.53 5,950,765.43 311,537.00 5.18 7,577.22 MWD+IFRAK-CAZ4C(6) 12,121.14 89.9 336.06 8,005.46 7,916.76 5,173.18 5,687.65 5,950,853.26 311,600.00 0.62 7,667.22 MND+IFRAK-CAZSC (6) 12,216.12 88.90 338.34 8.006.38 7,917.68 5,260.73 -5,724.45 5,950,941.67 311,465.39 2.66 7,766.08 MWD+IFRAK-CA7-SC(6) 12,311.41 88.17 338.74 8,008.82 7,920.12 5,349.39 -5,759.30 5,951,031.14 311,432.65 0.87 7,844.40 MWD+IFR-AK-CAZ-SC(6) 12,406.40 88.42 337.65 8,011.64 7,922.94 5,437.54 -5,794.57 5,951,120.12 311,399.54 1.18 7,932.65 MWD+IFRAK-CAZSC(6) 12,501.61 89.62 336.72 8,013.27 7,924.57 5,525.28 -5,831.48 5,951,29.73 311,364.77 1.59 8,021.73 MND+IFRAK�CAZ-SC(6) 12,59610 94.43 340.61 8,009.91 7.921.21 5,613.76 -5,866.04 5,951,298.01 311,332.37 6.50 8,19.72 MWD+IFRAK-CAZSC(6) &15@018 4:59:36PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips ER @ ConocoPhilli s p Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-05 Project: Western North Slope TVD Reference: MTS -05 Actual @ 88.70ush (Actual D19) Site: GMT1 Lookout Pad MD Reference: MTB -05 Actual @ 88.70usft (Actual D19) Well: MT6-05 North Reference: True Wellbore: MT6.05 Survey Calculation Method: Minimum Curvature Design: MT6-05 Database: EDT 14 Alaska Production Survey Annotation 4.1/2" x 6" - MT6.05 T2.3 8/152018 4:59.36PM Page 8 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS *WS aFJ4N DLS Northing Eaating Section Survey Tool Name (ash) (°) (1) (Mg) (uah) (ash) (ash) ( N I (h) (•hi (h) 12,691.58 9258 342.28 8,004.13 7,915.43 5,703.51 5,89649 5,951,388.46 311,309.42 2.63 8,195.60 MWD+IFRAKCA7SC(6) 12,787.02 92.78 343.21 7,999.68 7,910.98 5,794.57 -5,924.49 5,951,480.17 311,278.34 1.02 8,281.16 MWD+IFR-AK-CAZSC(6) 12,881.97 88.63 341.15 7,997.69 7,908.99 5,884.92 -5,953.53 5,951,571.20 311,251.50 3.96 8,366.73 MND+IFRAK-CAZSC (6) 12,977.36 88.10 338.17 7.999.58 7,910.88 5,974.34 -5,986.68 5,951,661.39 311,220.54 3.51 8,454.42 MWD+IFR-AKCAZSC(6) 13,073.05 87.86 337.16 8,002.95 7,914.25 6,062.79 5,023.02 5,951,750.69 311,186.36 1.08 8,543.63 MWD+IFRAKCAZSC(6) 13,168.20 89.10 335.70 8,005.47 7,916.77 6,149.97 5,061.D5 5,951,838.76 311,150.46 2.01 8,633.07 MWD+IFRAKCAZSC(6) 13,263.49 88.87 333.45 8.07.16 7,918.46 6,238.01 5,101.95 5.951,925.71 311,111.66 2.37 8,723.65 MWD+IFRAKCAZSC(6) 13,359.31 87.92 332.72 8,009.84 7,921.14 6,321.42 5,145.31 5,952,012.20 311,070.39 1.25 8,815.47 MWD+IFRAKCA7SC(6) 13,454.46 93.01 333.73 8,009.07 7,920.37 6,406.33 5,188.16 5,952,098.12 311,029.62 5.45 8,906.68 MND+IFRAKCAZ-SC (6) 13,549.84 94.85 333.95 8,002.54 7,913.84 6,491.74 5,230.11 5,952,184.52 310,989.76 1.94 8,997.43 MWD+IFRAKCAZSC(6) 13,645.06 95.04 333.96 7,994.33 7,905.63 6,576.97 5,271.76 5,952,270.73 310,950.19 0.20 9,087.94 MND+IFRAKCAZSC (6) 13,740.32 95.61 333.86 7,985.49 7,896.79 6,662.15 5,313.47 5,952,356.90 310,910.56 0.61 9,178.47 MWD+IFRAKCAZSC(6) 13,785.00 95.61 333.86 7,981.12 7,892.42 6,702.07 5,333.6 5,952,397.28 310,891.95 0.00 9,220.92 PROJECTED to TD Annotation 4.1/2" x 6" - MT6.05 T2.3 8/152018 4:59.36PM Page 8 COMPASS 5000.14 Build 85 Cement Detail Report MT6-05 String: Conductor Cement Job: DRILLING ORIGINAL, 5/11/201800:00 Cement Details Description Conductor Cement Cementing Start Date 2/6/2016 14:00 Cementing End Date 12/6/201616:00 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) I Cement Conductor 36.5 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? INo I Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) 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 (belt Yield (Wisack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gap Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (pail Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 8/13/2018 Cement Detail Report MT6-05 String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details DescriptionCementing Surface Casing Cement Start Date 5/14/2018 23.00 Cementing End Date 5/15/2018 02:38 Wellbore Name MT6-05 Comment Cement Stages Stage # 7 Description Surface Casing Cement jObjective Cement Surface Casing Top Depth (ftKB) 36.5 Bottom Depth (ftKB) 2,014.5 Full Return? Yes Vol Cement... 169.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 8 Q Pump Final (bbl/... 3 Q Pump Avg (bbl/... 8 P Pump 420.0 Final (psi) P Plug Bump (psi) 9 Recip? 1 Yes I Stroke (ft) 120.00 INo Rotated? I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) 1121/4 Drill Out Diameter (in) Comment 169 bbls good cement to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 36.5 Est Btm (ftKB) Amo (sacks) 1,514.0 ,04 Class LiteCRETE Volume Pumped (bbl) 357.0 Yield (ft /sack) 1.92 Mix H2O Ratio (gal/sa... 6,8 Free Water (%) 1 Density (Ib/gal) Plastic Viscosity (cP) 11.00 258,000.0 Thickening Time (hr) 4.52 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description 1 Estimated Top (ftKB) 1,514.0 Est Btm (ftKB) IAUWnt (sacks) 2,014.5 50 Class G Volume`Prped (bbl) 72.3 Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... 5.11 Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) 15.80 145,000.0 Thickening Time (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 811312018 a Cement Detail Report MT6-05 s� " String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details Description Intermediate Casing Cement 15/22/201 Cementing Start Date /22/2018 04:30 Cementing End Date 5/22/2018 07:30 Wetlbore Name MT6-05 Comment Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Isolate 9-5/8" Casing Shoe Top Depth (ftKB) 7,921.0 Bottom Depth (ftKB) 8,920.8 Full Return? Yes ' Vol Cement... Top Plug? Yes Stm Plug? Yes O Pump [nit (bbl/m...D 8 Pump Final (bbl/... 3 O Pump Avg (bbll... 8 P Pump Final (psi) 530.0 P Plug Bump (psi) Recip? Yes Stroke (ft) 7.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill 183/4 Out Diameter (in) Comment Did not bump plug, floats held. CIP = 7:21 Hrs Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 7,921.0 Est Bon (ftKB) 8,421.0 A nt (sacks) 104 Class G a Pumped (bbl) 42.7 ✓ Yield (ft'/sack) 2.3� Mix H2O Ratio (gaesa... 13.09 Free Water (%) Density (Ib/gal) 12.20 147,00f) Plastic Viscosity, (0) 0 Thickening Time (hr) 8.00 prStr 1 (psi) dditives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,421.0 Est Bon (ftKB) 8,120.9 241 Amount (sacks) - Class a Pump etl (bbl) G 49.8 Yield (ft /sack) 1.16 Mix H2O Ratio (gallsa... 5.0 Free Water I%) 1 Density (lb/gal) Plastic 15.80 138,000.0 viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 14.45 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 8113/2018 1r Cement Detail Report MT6-05 Job: t t Dr. ,1 String: Liner Cement DRILLING ORIGINAL, 5/11/201800:00 Cement Details Description Liner Cement 151901901816:30 Cementing Start Date Cementing End Date 15/29/20181930 Wellbore Name MT6-05 Comment Cement Stages Stage # 1 Description Liner Cement Objective Cement liner Top Depth (ftKB) Bottom Depth (ftKB) 9,664.0 11,164.0 II Retur9? Na Vol Cement... 5.0 Top Plug? No Btm Plug? No o Pump Init (bbl/m... 2 1 O Pump Final (bbl/... o Pump Avg (bbl/... 2 P Pump Final (psi) P Plug Bump (psi) 580.0 Recip? Stroke (it) No Rotated? Nc Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 32.2 bb12.2 Lead, 26 bbl 15.8 ppg Tail. / — S�i i.Fo ��.ra.a�-�, 5pl 9, Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description I Estimated Top (ftKB) 9,664.0 Est BIT(ftKB) 10,664.0 unt (sacks) 8 Class G Volume Pumped (bbl) 32.2 Y' tl p/sack) 2.30- Mix H2O Ratio (gal/sa... 13.16 Free Water I%) Density (lb/gal) 12.20 Plastic Viscosity (cP) 13.8 Thickening Time (hr) 6.00 CmprStr 1 (psi) ditives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimatetl Top (ftKB) 10,664.0 Est Btm (ftKB) 11,164.0 Amount (sacks) 126 Class Volume G 26.0 Pumped (bbl) Yield m/sack) 1.16 Mix H2O Ratio (gal/sa... 5.08 1 Free Water I%) Density (Ib/gal) 15.80 Plastic Viscosity (CP) 107.9 Thickening Time (hr) CmprStr 4.50 1 (psi) Additives Atltlitive Type Concentration Conc Unit label Page 111 ReportPrinted: 8/13/2018 1r Page 111 Report Printed: 8/13/2018 Cement Detail Report MT6-05 String: Cement Plug Job: DRILLING ORIGINAL, 5/11/2018 00:00 Cement Details Description Cement Plug Cementing Start Date Cementing End Date Wellbore Name 6/12/201821:30 6/12/201822:30 MT6-OSPBi Comment Cement Stages Stage # 1 W, Description Abandonment Plug Objective Top Depth (kK6) Isolate BHA#7 & 11,127.5 Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug production #1 11,233.0 Yes No No O Pump Init (bbl/m... 6 O Pump Final (bbl/... 3 p Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 400.0 Yes 30.00 No Tagged Depth (ftKB) 10,627.0 Tag Method ill Depth Plug Drilletl Out To (ftKB) Drill Out Diameter (in) Drill Bit 28.0 8 Comment Abandonment plug 11,233'to TOC 10,627' Polished off plug to 11,127.5' Cement Fluids & Additives Fluid F1 id Type Abandonment Fluid Description Estimated Tap (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Cement 11,127.5 11,233.0 121 G 22 g Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) 1.06 Density (Ib/gaq Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 4.33 16.50 130.0 6.50 Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 8/13/2018 r STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: 7It� P.I. Supry `U BOPE Test Report for: GMTU MT6-05 Comm Contractor/Rig No.: Doyon 19 - PTD#: 2180450 ' DATE: 6/28/2018 " Inspector Adam Earl Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Bjorhus/Reinhardt Rig Rep: Torres/Agnes Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopAGE180630153519 Rams: Annular: Valves: MASP: Type Test: BIWKLY 250/3500" 250/3500' 250/3500• 3100 - Related Insp No: FLOOR SAFTY VALVES: Quantity TEST DATA Upper Kelly__ 1 - P . MISC. INSPECTIONS: _ 1 - _ MUD SYSTEM: Ball Type ACCUMULATOR SYSTEM: _P _ Inside BOP P/F P Visual Alarm 0 Time/Pressure P/F Location Gen.: P Trip Tank _P P - System Pressure 3050 P - Housekeeping: P_ Pit Level Indicators P P " Pressure After Closure 1400 P " PTD On Location P Flow Indicator P P 200 PSI Attained 26 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 155 P Well Sign _ P H2S Gas Detector P P Blind Switch Covers: All stations P Drl. Rig P__ MS Misc 0 NA Nitgn. Bottles (avg): 4AIM - P' Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity Size P/F Stripper Quantity P/F Upper Kelly__ 1 - P . Lower Kelly _ 1 - _ P Ball Type I_' _P _ Inside BOP 1 " P FSV Misc 0 NA BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 135/8 - P #1 Rams _1 _ 31/2x6 - P . #2 Rams 1 - blind - P" #3 Rams 1 '31/2x6 P #4 Rams 0 NA #5 Rams 0 _NA #6 Rams 0 NA Choke Ln. Valves 1 . 31/8 P HCR Valves 2 - 3 1/8 - P " Kill Line Valves 2- 3118 P - Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 Test Results Remarks: 4 and 4.5 test jts. Good test CHOKE MANIFOLD: Quantity P/F No. Valves 14 P. Manual Chokes 1 P - Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 5 - 21 8045 29544 Originated: Delivered to: r • 27 -Jul -18 Schlumberger 1 } AOGCC 27Ju118JW04 PTS - PRINT CENTER MT6-03 is located in a federal oil and gas unit. Only with \ ATTN: Natural Resources Technician II respect to the MT6-03 Well Data, CPAI herebywaives its right 6411 A Street 'Alaska Oil& Gas Conservation Commision to indefinite confidentiality, under S U.S.C. 552(b)(4) and Anchorage, AK 99518 L! 333 W. 7th Ave, Suite 100 (9). Nothing in this communication should be construed as a (907)273-1700 main (907)273-4760 fax „my& Anchorage, AK 99501 waiver of indefinite confidentiality on any other wells. SERVICE ORDER SERVICE Color WELL NAME API If # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA DATELOGGED Prints CD's MT6-05 50.103-20771-00 DOMD-00056 reater Mooses Toorq Memory Cement Eval FINAL FIELD 29 -Jun -18 1 1 77 TDIF -JUL 1 1 I.1../7 Transmittal Transmittal Receiitt X Print Nam Signature Please return via courier or sign/scan and email a copy to Sc Alaska PTSPrintCenter slb.com A Transmittal Receipt signature confirms that a package (box, �J nvelope, etc.) has been received and the contents of the /[ L7� package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this mberger. point. SLB Auditor- :7-W THE STATE juj /�� Alaska fail and Gas 01ALA�cc K—A Conservation Commission GOVERNOR BILI. WALKER Weifeng Dai Staff Drilling Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-05 Permit to Drill Number: 218-045 Sundry Number: 318-245 Dear Mr. Dai: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alcsko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this Is day of 2018. Sincerely, Ca��T~ oerster Commissioner RBDMS-,2- JUN 18 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 REMEIE h75 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 ❑ BHA Abandonment w/ RA Source El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Q Stratigraphic ❑ Service 218-045 3. Address: S. API Number: 700 G St, ATO 1704, Anchorage, AK 99501 50-103-20771-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A MT6-05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Progeny Designation (lease Number): 10. Field/Pool(s):t)%w>< AA081798: AA081818, AA092346 Greater Mooses Tooth Unit, A)pinadindefined OilA 6 (3 {g 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): 12037 8042 12037 8042 3100 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 115' 115' Surface 1978' 13.375" 2014' 1976' Intermediate 1 8887' 9.625" 8921' 7122' Intermediate 2 11131' 7" 11163' 8006' Liner Perforation Depth MD (ft): Perforation Depth TVD fty. Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A WA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development Q Service ❑ 14. Estimated Date for 6/4/2018 15. Well Status after proposed work: Commencing Operations: OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 6/3/2018 Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Weifeng Dai Contact Name: Weifeng Dai Authorized Title: Staff Drilling Engineer Contact Email: weifen .dai CO .Com /' Contact Phone: 907-263-4324 6�ZO� Authorized Signature: '1/ � Date: � Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I s✓-, •lJ/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: MITired? Yes ❑ No •7 / I Post inRial Ex Exception Spacing Exception Required? Yes No Subsequent Form Required: — yQ ❑ l O [ BY PAPPROVED Approved by: COMMISSIONER THE COMMISSION Date: S L/`� WW l3• Form 10-403 Revi 4/2017 A roved a I' a pp pp�^ �',�`s a4,J1Al-a a i„�\ f4. Atm he the date of approval. 1p. SubmR Formad Attachments in Duplicate ConvcoPhlllips Post Office Box 100360 Anchorage, Alaska 99510-0360 June 12, 2018 Commissioner Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 RE: Sundry Approval Request for MT6-05 (218-045) Dear Commissioners: ConocoPhillips Alaska, Inc hereby requests approval to abandon a drilling BHA with a radioactive source and cap with a 100' cement plug. The drilling BHA became stuck shortly after drilling into the Kingak shale below the targeted Alpine C sand. The shale became unstable and packed off around the BHA. Attempts to free were exhausted with no success. The drill pipe was severed above the BHA but the flared end of the free joint became stuck. The pipe was backed off two connections above sever point to free the drill string again. BHA will be left in hole and capped with a 100' cement plug (dyed red). Total depth of well is 12,037' MD, and the bit is at 11,870' MD. Initial sever point of the BHA, top of Fish #1, was around 11,342' MD. Drill string was backed off around 11,234' MD to separate from top of Fish #2. Cement plug will be spotted from approximately 11,134' MD to 11,234' MD and will be tagged. Once cement is set, the lateral will be re -drilled by kicking off a whipstock set inside the 7" intermediate casing. Operations will then return as outlined in the PTD. If you have any questions or require further information, please contact me at (907) 263-4324. Sincerely, / p Weifeng Dai Staff Drilling Engineer MT6-05 BHA Abandonment 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface 13-318" 68 ppf L-80 TXP to TD Surface Casing @ 2,041' MD / 1,980'TVD cemented to surface 9 5/8" 40 ppf L-80 H563 (to 1,335') 9 5/8" 40 ppf L-80 BTC (to 3,981' MD) 9 5/8" 40 ppf L-80 TXP (to 6,790' MD) 9 5/8" 40 ppf TN -80 HC TXP (to TD) @ 8,921' MD / 7,125' TVD TOC of 95/8-7.921 ft MID O Top Alpine C 10,945' MD / 7,979' TVD Abandonment Plan: 1) Bottom offish #1 @11,870'. 2) Top offish #1 @11,342'. 3) Bottom offish #2 @ 11,298'. 4) Top offish #2 and bottom of cement @ 11,234'. 5) Top of cement @ 11,134'. RA source depth: Density 11,817.78', Neutron 11,807.53'. a 3 O - 'i. Fish N2 7" 26 ppf L-80 Tenaris Blue/H563 Liner to 11,163 MD / -7,975' TVD @ 83 deg O onocoPhillips ADVANTAGE String Report - Run #6 BAF�UGHES a6Emmp� Operator ConocoPhillips Alaska, Inc. Field Alpine Facility MT6 Well MT6-05 Wellbore MT6-05 String Components Rig Job MT6-05 Component S/N Mfr Gauge OD ID FN FN Thread Length Total OD I OD Len. Len # in in in in ft ft ft 19 Drill pipe RIG Grant Prideco 4 3.340 (BP) DS38 - DS38 0.00 336.80 18 Sub - X/0 Rig Rig 4 3.340 (BP) DS38 - XT39 10.05 336.80 17 HWDP x 2 Rig GRANT-PRIDECO 5 4 2 9/16 (BP) XT39 - XT39 61.17 326.75 16 Jar 1400-1015 WFD 4 3/4 2 1/4 43/4 1.45 (BP) XT39 - XT39 29.03 265.58 15 HWDP x 3 Rig GRAM-PRIDECO 5 4 29116 (BP) XT39 - XT39 91.44 236.55 14 NM Sub - X/O Rig Rig 4 15/16 2 1/4 (BP) XT39 - 3 1/2 IF 1.65 145.11 13 Drill pipe - compressive DR30391 INTEQ 43/4 4 211/16 43/4 6.70 (BP) NC38 - NC38 30.52 143.46 12 Drill pipe - compressive DR30382 INTEQ 43/4 3 1/2 2 11/16 43/4 6.60 (BP) NC38 - NC38 30.87 112.94 11 NM Sub - Float DR18565 BHGE/Plunger 43/4 2 1/4 (BP) 3 1/2 IF - 3 1/2 IF 3.50 82.07 10 NM Sub - filter DR31418 INTEQ 4 3/4 2 1/2 (BP) 3 1/2 IF - 3 1/2 IF 3.12 78.57 9 NM Sub - Float DR18570 BHGE/Plunger 43/4 2 1/4 (BP) 3 1/2 IF - 3 1/2 IF 3.49 75.45 8 NM Stab - string DR19803 BHGE 5 7/8 4 3/4 2 1/4 43/4 2.00 (BP) 3 1/2 IF - 3 1/2IF 4.75 71.96 7 NM Sub - stop 13270689 INTEQ 5 1 1/2 (BP) 3 1/2 IF - T2 2.41 67.21 6 SDN 11839327 INTEQ 5 1 1/2 (BP) T2 - T2 17.16 64.80 5 BCPM 11763735 INTEQ 5 13/4 (BP) T2 - T2 10.82 47.64 4 MWD - stab - mod 14443612 INTEQ 5 7/8 5 1 1/2 5 1.50 (BB) T2 - T2 3.29 36.82 3 OnTrak - MWD 11677222 INTEQ 5 1 1/2 5 (BP) T2 - T2 23.10 33.53 2 ATK Steerable Stab 13849259 INTEQ 5.024 1.024 5 3.73 (BP) T2 - 3 1/2 Reg 9.62 10.43 1 1 Bit - PDC - fixed cutter 5282206 HCC 6 6 3 1/2 Reg 0.81 0.81 19 String components with a total length of 336.8 ft. Run Details Run Depth In Depth Out Time In Time Out Total Dist Hold Dist Steering Dist Ribs -Off Dist Buoyed BHA Wt Buoyed Wt below jars I ft ft ft ft ft ft klbf I klbf 6 1 1 1 1 0.00 1 0.00 0.00 15.13 11.23 Size Type/Mfr Nozzles Bit TFA Grading Details In MD/TVD Out MD/TVD Progress Time TBR �^ in/32 in -2 I O D L B G O R ft ft ft hours 6 D406TX /HCC 3x -.3x10 1 0.4165 # Size Grade DrillpipeDetails Connection OD ConnettionI0 Act Linear Weight Nom Linear Weight in in in Ib/ft Ib/ft 19 4 G-105 1 4 7/16 1 2 13/16 15.29 14.00 Description Details Distance to Bit Spiral'Type elatle Type Blade OD Blade Length Blade Width # ft in in n B Stab - string 69.41 Spiral Integral 5 7/8 18.00 2 1/2 4 MWD -stab -mod 34.43 Spiral Integral 5 7/8 12.00 2 1/2 Page 1 Schwartz, Guy L (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Tuesday, June 12, 2018 11:19 AM To: Rixse, Melvin G (DOA) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: [E)(TERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Mel, Thanks for letting us know, we have put together Sundry and shall submit today. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, June 12, 2018 11:11 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Weifeng, AOGCC may want to witness the tag for TOC. Have you submitted your sundry yet? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (9D7-793-1231) or (IAelvin.Rixse@alaska.gov). cc. Jim Regg From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent: Monday, June 11, 2018 2:36 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: RE: [EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Mel and Guy, We finally backed off successfully with string shot on Sunday, we recovered all the pipe above the string shot connection. Currently getting ready to pick cement stinger. The attached is the cement plan. The bottom of the cement plug is 11,234' which is the top of 2"d fish. The top of cement will be dressed off to 11,118' with clean out BHA. Then whipstock will be set on top of the cement and mill window exit. With that being said, I will submit sundry to cover the cement job, please verbally advice if the plan looks good to you as we scheduled to pump cement tomorrow. Weifeng Office: ( 907)-263-4324 Cell Phone: (907)-342-9508 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Sunday, June 10, 2018 12:44 PM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Cc: Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov> Subject: Re: [EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Weifeng, Thank you for the update. When you get to a point where you are planning to pump your red cement can you call call me and forward me a brief plan? My phone is 907-223-3605. Mel Rixse On Jun 10, 2018, at 10:17 AM, Dai, Weifeng <Weifeng.Dai@conocophillips.com> wrote: Guy and Mel, Just want to give you a quick update here. We did severing tool and successfully separated from the BHA and left BHA in hole @ 14:30 6/8/2018, the bottom of BHA 11,870', top of fish @ 11,342'. But unfortunately, when rig attempt to work pipe out of hole, hole packed off again and stuck at 11,298' MD. Then run perf gun and shot hole from 11,276 to 11,285. Built good circulation to 8bpm, attempted to work pipe free but failed. Currently we are attempt to back off with string shot. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Dai, Weifeng Sent: Thursday, June 7, 2018 10:55 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Thanks Guy, The abandonment didn't go very well. We perforated at 11,526' last night, above 179' below the top of shale, we were not able to build good circulation and hole packed off. We are currently get ready to run in hole another gun to perforate at 11,346'. If we are able to get good rate, then we will try to cut the string at the same depth. Then pump cement from here to 200' inside the 7" casing shoe. I will keep you and Mel updated. Weifeng Office: ( 907)-263-4324 Cell Phone: (907)-342-9508 From: Schwartz, Guy L (DOA) <guy.schwartz(a@alaska.gov> Sent: Thursday, June 7, 2018 10:00 AM To: Dai, Weifeng <Weifeng.Dai(a)conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: RE: f EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Weifeng, I will be out of the office for several days starting tomorrow. Can you copy Mel Rixse on all emails and updates. Any update on the fishing or abandonment? 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 low. 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 (Guv.schwariz@alaska gov). From: Dai, Weifeng[mailto:Weifeng.Dai@conocophillips.com] Sent: Tuesday, June 05, 2018 10:27 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.eov> Subject: RE: [EXTERNAL]RE: MT6-05 Update and Plan Forward (PTD 218-045) Guy, I am working on the sundry and I will update on drilling progress twice a week. Feel free to check with me if you don't receive updates. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Sent: Tuesday, June 5, 2018 9:28 AM To: Dai, Weifeng <Weifena.Dai@conocophillips.com> Subject: [EXTERNALjRE: MT6-05 Update and Plan Forward (PTD 218-045) Sounds like you need to start getting a sundry together to abandon the BHA. Agree with your procedure as outlined below and you have verbal approval to proceed. Once you have a better idea of what the cementing will look like you can finalize the sundry procedure. Also, I need updates on drilling progress twice a week. Joe was doing that before. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIAL!!' 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- 12261 or (Guy.schwartz@alaska aov(. From: Dai, Weifeng[mailto:Weifeng.Dai@conocophillips.com] Sent: Tuesday, June 05, 2018 8:32 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.eov> Subject: MT6-05 Update and Plan Forward Guy, Below is the summary of what we did yesterday and plan forward, please let me know if you have any questions. Operation Yesterday: 1. Performed injectivity test, broke down formation @ % BPM with 2,860psi which is 14.9ppg EMW. 2. Bullhead 100bbls 9.2 OEM in the drill pipe. 3. Blind back off with gradual increase left hand surface torque, inadvertently backed off 4" DP connection at —4,900' with ^10k ft -lbs. Pump 9.2ppg OBM in the back side of drill pipe, the annular is over balanced too. 4. Screw back drill pipe connection. Plan Forward: 1. Wait for E -line tool and personnel, ETA around noon today. 2. Rig up surface equipment, tractor down E -line perforation gun, perforate hole in the 2 drill pipe joint above BHA. 3. Establish circulation to high rate, POOH E -line tool. 4. Run severing tool in hole at the connection of 31a joint wear knot drill pipe, pumping down the tool as necessary. 5. Ignite severing tool, part from BHA. 6. Circulate hole clean and POOH. 7. RIH 3-1/2" cement stinger and spot 17 kick off plug, we will dye the cement. <image001.jpg> Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Dai, Weifeng Sent: Monday, June 4, 2018 8:39 PM To: Robinson, Shon D <Shon.D.Robinson@conocophillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com> Subject: RE: MT6-05 Plan Forward Operation update: We did the injectivity test and break down formation with 14.8ppg EMW (in line with Geo's fracture gradient of Kingak), then we bullhead drill string volume of 9.2ppg OBM kill weight fluid. After that, we performed blind back off with gradually increased torque and it appears that the 14# drill pipe connection XT39 down at ^7,000' backed out inadvertently with 10k LH surface torque other than expected 3-1/2" IF connection, no luck there. We are going to circulate 9.2ppg OBM in the back side of drill pipe then screw back the connection with -23K surface torque as per plan. Then wait for E -line tool and people arrival tomorrow afternoon to resume operation. Weifeng Office: ( 907)-263-4324 Cell Phone: (907)-342-9508 From: Dai, Weifeng Sent: Monday, June 4, 2018 1:09 PM To: Doyon 19 Company Man <doyonl@conocophillips.com>; Doyon 19 Rig Engineer <n2059@conocophillips.com>; Alpine Field Drilling Supervisor <aa�1969@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Marushack, Andy J <_A_ndy.J•Marushack@conocophillips.com>; Polasek, Tom G <Tom.G.Polasek@conocophillips.com>; Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Robinson, Shoo D <Shon. D. Robinson@conocophillips. com>; 'Alvord, Chip' <C_h_ip. Alvord@conocophillips. com> Subject: MT6-05 Plan Forward Thanks for everyone's input, below is the plan forward worked out in the meeting. Plan for Today: 1. Rig will conduct injectivity test in the drill pipe, the goal is to establish consistent flow rate with less than 3,000 psi surface pressure (15.7 ppg EMW). 2. If injectivity test result is positive, we will displacing drill pipe volume ("'125bbs) with 9.1ppg Versapro OBM. If not, we will re -convene again to determine the path forward (most likely to wait E -line tool to punch hole in drill string tomorrow). • If injectivity happens sooner than later and creating severe static losses (likelihood could be low), we will switch to water based system with spacer (per MI) ahead to enable us keep up with fluid requirement. 3. We will attempt to blind back off after finish displace drill pipe. The left hand torque limit set @ 12.5k ft - Ib at surface, move the pipe up and down to transfer the torque down hole. The target connections we try to back off is 3-1/2" IF close to the BHA. If we back off successfully, we will circulate 9.1ppg CBM around, a marker will be pumped to calculate back off connection depth. • If back off happens shallower than expected, displace to kill weight OBM in annular before attempting to screw back on. Plan for Tomorrow: 1. Pollard and SLB will ship out puncture and severing tool, Welltec will ship out tractor. The Welltec tractor engineer and SLB E -line engineer ETA is Tuesday (5� June) afternoon. 2. After tractor, SLB a -line tool and people arrive on location, rig up surface equipment for E -line operation. 3. Run Pollard 2" perf gun on Welltec tractor, punch hole on the pipe body of bottom HWDP. 4. Pull E -line tool above the perforations, attempt to confirm circulation through puncture, POOH and lay down E -line tool. 5. Displace 9.1ppg OBM from surface to surface. 6. Prepare for next a -line run, either severing tool or Chem cutter or string shot, TBD. This shall put us through next 36-48 hours, I will send out update plan as necessary. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 Schwartz, Guy L (DOA) From: Sent: To: Cc: Subject: Guy, Ref: KLU Al Sundry #318-226 Alex Vaughan <AVaughan@petroak.com> Friday, June 15, 2018 9:28 AM Schwartz, Guy L (DOA) Steve Tyler KLU Al Sundry #318-226 FOA will be performing a non -pressurized and 1000psi pressured logging run for the KLU Al Cement Isolation Scanner program. Below is the pertinent information copied from the most current draft field program. 8. RIH w/ tools performing P/U weight every 1000ft 9. Stop @ 8030' (100' above PBTD) and log up at 10deg 1.5" Resolution. Estimated logging speed is 2800- 3000ft/hr. 10. Perform repeats from 4400' to 8030' as needed at 10deg .6" Resolution, to ensure cement isolation within Sterling and Beluga. 11. Perform minimum 500ft repeat pass to confirm data repeatability 12. After main pass is complete. RI to 8030'. Pressure wellbore to 1,000 psi. log up at lOdeg 1.5" Resolution. Estimated logging speed is 2800-3000ft/hr. 13. Perform repeats from 4400'to 8030' as needed at 10deg .6" Resolution, to ensure cement isolation within Sterling and Beluga. 14. Perform minimum 500ft repeat pass to confirm data repeatability Alex Vaughan Drilling Engineer Mobile 907-748-5478 avaug han (a)petroak. com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,7,?�j -7/101l16 P.I. Supervisor FROM: Guy Cook Petroleum Inspector Section: 6 Township: 10N Drilling Rig: Doyon 19 Rig Elevation: 34 ft Operator Rep: Kenny Harding Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ Surface: 13 3/8" - 0. D. Shoe@ Intermediate: 9 5/8" 0. D. Shoe@ Production: 7" 0. D. Shoe@ Liner: Csg 0. D. Shoe@ Tubing: Feet 0. D. Tail@ Plugging Data: Test Data DATE: June 14, 2018 SUBJECT: Well Bore Plug Verification GMT MT6-05 Conoco/Phillips PTD 2180450; Sundry 318-245 Range: 3E Total Depth: 12037 ft MD Suspend: Meridian: Umiat Lease No.: AA081798, AA081818 AA092346 P&A: See Remarks I/ Type Plug Founded on Depth (Btm) Casing Removal: 79 Feet Csg Cut@ Feet 2014 Feet Csg Cut@ Feet 8921 Feet Csg Cut@ Feet 11163 Feet Csg Cut@ Feet Feet Csg Cut@ Feet Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole ' Retainer 11234' MD ' 11127.5' MD 16.5 Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Plug back due to stuck BHA with radioactive source at 11342 ft MD. The cement plug was founded on the fish in the hole. No pressure test was required after the cement tag. The cement was not dyed red by mistake. A sample of the cement gathered from the shakers while dressing out the plug showed good cured cement. 106.5' of cement is in place on top of the fish. 15K was set on the plug twice with no signs of downward movement. Attachments: Photo of cement gathered from the shakers rev. 04-06-18 2018-0614_Plug_Verification_GMTU_MT6-05—gc Plug Verification — GMTU MT6-05 Photo by AOGCC Inspector G. Cook 6/14/2018 Cement sample taken from returns at shale shakers STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P 1 Snpry ��- L7It BOPE Test Report for: GMTU MT6-05 - Comm Contractor/Rig No.: Doyon 19 PTD#: 2180450 DATE: 6/13/2018 Inspector Guy Cook Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Kenny Harding Rig Rep: David Evans Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopGDC180615082250 Rams: Annular: Valves: MASP: Type Test: BIWKLY 250/3500 ' 250/3500 250/3500 ' 3100 ' Related Insp No: MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Well Sign P _ DO. Rig P Hazard Sec. P_ Mise NA FLOOR SAFTY VALVES: TEST DATA MUD SYSTEM: Visual Alarm Trip Tank Quantity P/F Upper Kelly _ _ 1 P _- Lower Kelly _ 1— P Ball Type 1 P ' Inside BOP 1 P ' FSV Mise 0 NA TEST DATA MUD SYSTEM: Visual Alarm Trip Tank P P ' Pit Level Indicators P P ' Flow Indicator P P Meth Gas Detector P -_ P ' H2S Gas Detector P P MS Mise NA NA BOP STACK: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3125 P Pressure After Closure 1500 P 200 PSI Attained 28 P Full Pressure Attained 160 P Blind Switch Covers: All Stations' P Nitgn. Bottles (avg): _ 4_P 2200 P ACC Mise 0 NA Quantity Size P/F Stripper 0 Quantity P/F NA Annular Preventer 1 '13 5/8" 5000 - P #1 Rams 1 - 3.5 x 6" P #2 Rams 1 - Blinds P #3 Rams 1 - 3.5 x 6" P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 . 3 1/8" 5000 P . HCR Valves 2 - 3 1/8" 5000 P ' Kill Line Valves 2 - 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 Test Results Remarks: 4" and 4.5" test joints used for testing. CHOKE MANIFOLD: Quantity P/F No. Valves _ _14 P Manual Chokes I P Hydraulic Chokes 1 P CH Mise 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 9 % From: Schwartz, Guy L (DOA) Sent: Tuesday, June O5, 2018 9:28 AM To: 'Dai, Weifenq' Subject: RE: MT6-05 Update and Plan Forward (PTD 218-045) Sounds like you need to start getting a sundry together to abandon the BHA. Agree with your procedure as outlined below and you have verbal approval to proceed. Once you have a better idea of what the cementing will look like you can finalize the sundry procedure. Awl )N. Also, I need updates on drilling progress twice a week.Xe was doing that before. 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 if, 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 (Guv schwanz@alaska aov(. From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.com) Sent: Tuesday, June 05, 2018 8:32 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: MT6-05 Update and Plan Forward Guy, Below is the summary of what we did yesterday and plan forward, please let me know if you have any questions. Operation Yesterday: 1. Performed injectivity test, broke down formation @ % BPM with 2,860psi which is 14.9ppg EMW. 2. Bullhead 100bbis 9.2 OBM in the drill pipe. 3. Blind back off with gradual increase left hand surface torque, inadvertently backed off 4" DP connection at —4,900' with —10k ft -lbs. Pump 9.2ppg OBM in the back side of drill pipe, the annular is over balanced too. 4. Screw back drill pipe connection. Plan Forward: 1. Wait for E -line tool and personnel, ETA around noon today. 2. Rig up surface equipment, tractor down E -line perforation gun, perforate hole in the 2M drill pipe joint above BHA. 3. Establish circulation to high rate, POOH E -line tool. 4. Run severing tool in hole at the connection of 31^joint wear knot drill pipe, pumping down the tool as necessary. This shall put us through next 36-48 hours, I will send out update plan as necessary. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 MISC. INSPECTIONS: STATE OF ALASKA Location Gen.: _P= Housekeeping: OIL AND GAS CONSERVATION COMMISSION Reviewed By: p �'Z3i P Standing Order Posted --P P.I.Supry.11 _P _ BOPE Test Report for: GMTU MT6-05 ✓ P Comm Contractor/Rig No.: Doyon 19 PTDN: 2180450 DATE: 5/16/2018 - Inspector Brian Bixby Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Ken Harding Rig Rep: David Evans Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopBDB 180517071638 I Rams: Annular: Valves: MASP: P Ball Type Type Test: INIT 250/ 3500, 250 / 3500 , 250 / 3500 3100 - Related Insp No: 1 - 3 1/2 x 6 - MISC. INSPECTIONS: TEST DATA P/F Location Gen.: _P= Housekeeping: P PTD On Location P Standing Order Posted --P Well Sign _P _ Drl. Rig P Hazard Sec. P Misc NA TEST DATA System Pressure MUD SYSTEM: P Pressure After Closure Visual Alarm P Trip Tank P P . Pit Level Indicators P P - Flow Indicator P P Meth Gas Detector P P - H2S Gas Detector P - P MS Misc 0 NA ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3020 P Pressure After Closure 1500 P 200 PSI Attained 25 P Full Pressure Attained _ 142 P Blind Switch Covers: _YES P Nitgn. Bottles (avg): 4k2150 P ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: 1 --- _ CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 F_ Stripper 0 NA No. Valves 14 P Lower Kelly _ 1 NT '/Annular Preventer —1- 135/8 P- I Manual Chokes 1 P Ball Type _1_._ P #1 Rams 1 - 3 1/2 x 6 - P Hydraulic Chokes 1 P Inside BOP 1 P #2 Rams 1 - Blind Rams- P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 - 3 1/2 x 6 -. P _ #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1' 31/8 - P- Quantity P/F HCR Valves 2 " 3 1/8 ' P - Inside Reel Valves 0 NA Kill Line Valves 2 ' 3 1/8 P -- Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 Test Results Test Time 7.5 Remarks: Test with 6" drill pipe, Tested all gas alarms. NOTE: The Upper Kelly valve failed was than ed out along with the the Kell valve because the new ones are already made up. I had to leave to catc a light so I did not withness the retest or the test of the Lower Kelly valve. The rest of the test was GOOD. r THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aiasko.gov Re: Greater Mooses Tooth Unit, Alpine Undefined Pool, MT6-05 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-045 Surface Location: 261' FNL, 3171' FEL, SEC, 6, TION, R3E, UM Bottomhole Location: 1358' FNL, 585' FEL, SEC. 26, TI IN, R2E, 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, Hollis S. French Chair IL DATED this w day of April, 2018. STATE OF ALASKA ; AL KA OIL AND GAS CONSERVATION COM16, . 5ION PERMIT TO DRILL 20 AAC 25.005 RECEIVED APR 10 2018 1a. Type of Work: tb. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑ 1c. S p oo ad for: Drill ❑� 'Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑� , Service - Winj ❑ Single Zone ❑� ` Coalbed as G"as Fydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: Con000Phillips • Bond No. 59-52-180 MT6-05 , 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 16919, TVD: - 7970 Greater Mosses Tooth Unit Alpine Undefined Oil , 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 261' FNL, 3171' FEL, Sec. 6, T1 ON, R3E, UM AA081798,AA081818,AA092346 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1354' FNL, 3186' FEL, Sec. 36, T11 N, R2E, UM 932,533,000,932,553,000,000,000,000 5/10/2018 Total Depth: 1358' FNL, 585' FEL, Sec. 26, T11 N, R2E, UM 9. Acres in Property: PAO 14. Distance to Nearest Property: 6091 .S Q5 1 1358' to AA081819 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70 15. Distance to Nearest Well Open Surface: x- 317060 y- 5945544 Zone -4 GL / BF Elevation above MSL (ft): 34 , to Same Pool: 4300' to MT6-03 16. Deviated wells: Kickoff depth: 1036 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: q0 rj8'degreesg@ Downhole: 3810 • Surface: 3100 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD I TVD MO TVD (including stage data) 42" 20" 78.6 H-40 Welded 79 361 36 115 115 10yds 16" 13-3/8" 68 L-80 H563/TXP 2018 36 36 2054 2033 942 sx 11.0 ppg Lead, 328 sx 15.8ppg Class G Tail 12-1/4" 9-5/8" 40 L-80 TXP/TN-80 8946 36 36 8982 7099 216 sx 15.8ppg Class G HC 67xB-3/4" 7" liner 26 L-80 BTC/Blue 2200 8800 6971 11000 7959 464 sx Class G 15.8 ppg cemented to linertop 6" 4.5" liner 12.6 L-80 TXP 5969 10950 79521 16919 7970 Uncemented open hole liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑ 20. Attachments: Property Plat ❑ DiveOP Sketch e Progra Seabed Report e Dri I g FluidPrTieto�Pam Shallow Hazard Anaysi's 8 20 AAC 25.050 requiremlents 8✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. r Contact Name: Weifeng Dai Authorized Name: Chip Alvord Contact Email: WeifeD .Dai c0 .Cam Authorized Title: Drilling Manager Contact Phone: 907-263-4324 Authorized Signature: -d Date: Commission Use Only Permit to Dri I _ API Number: 'Q Permit Approval See cover letter for other Number: p�, 50. 3 - 0Q- Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbeA methane, gas hydrates, or gas contained in shales: Other:'� O Sod / �� Samples mq'd: Yes ❑ No R1 Lr� Mud log req'd: Yes No E][r� 14 3 �5` (-L H,S measures: Yes No,❑ Directional svy roq'd: Yes No ❑l ( Spacing exception req'd: Yes ❑ No Lrl Inclination -only svy req'd: Yes ❑ No [ Post initial injection MIT req'd: Yes ❑ElNo \� ti IBJ I Ie� APPROVED BY Approved T DateSubmit Form and /,,0 lr y//6//� - ye_ y-lY-lb ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 03, 2018 Alaska Oil and Gas Conservation Commission 333 West 7a' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-05 Dear Sir or Madam: Y ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the GMT -1 drilling pad with rig Doyon 19."The intended spud date for this well could be as early as 05/05/2018. MT6-05 is planned to be a horizontal Alpine Upper C and Alpine Lower C production well, with the Alpine Upper C lateral covered in the MT6-05L I PTD. The 16" surface hole will above the C-30 sand and then 13-3/8" casing will be set and cemented to surface. The intermediate 1 hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12- 1/4" intermediate #I section will be drilled into the top of the HRZ. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. The intermediate 2 will be drilled with a 7" steerable liner drillmSassembly, ultimately landing in the Alpine C sand. This assembly will consist of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" undereamer for increased annular clearance. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations.The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. The 6" production section will then be horizontally drilled and completed in the Alpine C reservoir. Alpine C sand lateral will be lined with 4-3/4" liner. 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 Weifeng Dai at 263-4324 (weifeng.dai@ConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, �fj��a cc: MT6-05 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Weifeng Dai Viet Nguyen ATO 1778 Staff Drilling Engineer Lanston Chin Kuukpik Corp A ation for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 MT6-05 Application for Permit to Drill Document co�a<oan�n�p: Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 ()9)............................................................ 3 2. Location Summary (Requirements of20AAC 25.005(c)(2)) ............................................ 3 Requirementsof 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of20AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20AAC25.005 (c)(4)) ........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c)(5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of20 AAC 25.005(c)(7)) ......................... 5 8. Drilling Fluid Program (Requirements of20AAC 25.005(c)(8)) ....................................6 9. Abnormally Pressured Formation Information (Requirements of20 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 20AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements of20AAC 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 Attachment1 Cement Summary ............................................................................................................... 10 MT6-05 APD Page 1 of 15 Printed. 4 -Apr -18 A ation for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 Attachment 2 Drilling Hazards Summary ................................................................................................. 10 Attachment 3 Completion Schematic........................................................................................................ 10 Attachment 4 Directional Plan................................................................................................................ 10 MT6-05 APD Page 2 of 15 Printed. 4 -Apr -18 FV 3tion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 1. Well Name (Requirements of 20 AAC 25.005 0) The well for which this application is submitted will be designated as MT6-05 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 261' FNL, 3171' FEL Sec. 6 TION ME UM ' NAD 1927 RKB Elevation 70.0' AMSL Northings: 5,945,544 7,970' Total Vertical De t& SS. Eastings: 317,060 Pad Elevation 34' AMSL Top of Productive Horizon eel 1354' FNL, 3186' FEL, Sec. 36, Ti 1N, R2E, UM NAD 1927 Measured De 11, RKB: 11 000' Northings: 5,949,853 Total Vertical De th RKB: 7,959' Eastings: 312,133 1 Total Vertical De th, SS. 7,879' Total Depth Upper C Lateral Toe 1358' FNL, 585' FEL, Sec. 26, TI IN, ME, UM NAD 1927 Northings: 5,955,194 Eastings: 309,583 Measured De th, RKB: 16,919' Total Vertical De th, RKB: 7,970' Total Vertical De t& SS. 7,900' Total Depth Lower C Lateral Toe 1358' FNL, 585' FEL, Sec. 26 T11N R2E, UM NAD 1927 Northings: 5,955,194 Eastings: 309,583 Measured De th, RKB: 16,919' Total Vertical Depth, RKB: 7,970' Total Vertical De t& SS. 7,900' Requirements of20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. / MT6-05 APD Page 3 of 15 Printed: 4 -Apr -18 Aztion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 4. Drilling Hazards Information(Requiremenrsof20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 1151115 10.9 52 54 13.375 2054/2033 14.5 910 1,330 9.625 8982/7099 13.5 3176 3,100 7 11000/ 7959 12.5 3,810 2,977 4.5 16919/7970 12.5 3 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP1 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 16./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) - 0.11 D _ [(10.9 x 0.052) - 0.1] x 115 = 54 psi OR ASP = FPP - (0.1 x D) = 910 - (0.1 x 115') = 899 psi 2. Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.11 D _ [(14.5 x 0.052) - 0.11 x 2033' = 1,330 psi OR ASP = FPP - (0.1 x D) = 3176 - (0.1 x 2033') = 2,973 psi 3. Drilling below first intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(13.5 x 0.052) - 0.1 ] x 7099 = 4,274 psi OR ASP =FPP-(0.1 xD) =3810-(0.1x7099') 3,100psi MT6-05 APD Page 4 of 15 Printed: 4 -Apr -18 !d ation for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 4. Drilling below production liner (711) ASP = [(FG x 0.052) — 0.11 D = [(12.5 x 0.052) — 0.1 ] x 7959 = 4,377 psi OR ASP= FPP — (0.1 x D) = 3773 — (0.1 x 7959) 2,977 psi (B) data on potential gas zones; 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 of20AAC25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConoccPhillips 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 Sae Weight Grade Conn. Length Top MD7TVD Btm MD/TVD Cement Program OD (in) (ice) (h) (re) (h) 20 42 79 H-40 Welded 80 Surf 115/115 Cemented to surface with 10 yds slurry H 563/ 563 Cement to Surface with 13-3/8 16 68 L-80 TXP 2,017 Surf 2,054 / 2,033 942 sx DeepCrete Lead at 11.0 ppg, 328 sx Class G Tail Slurry at 15.8 ppg TXP/ 9-5/8 12-1/4 40 L-80 TN -80 8945 Surf 8,982 / 7,099 216 sx Class G Tail at 15.8 ppg HC 7 6x8- 26 L-80 BTC/ 10,963 Surf 11,000 / 7,959 464 sx Class G 15.8 ppg cemented to liner 3/4 Blue top at 8,700' MD 4-1/2 n/a 12.6 L-80 563 9,763 Surf 10,600 / 7,903 n/a 4 1/2 6 12.6L-80 UP 6,068 10,850 / 7,940 16,918 / 7,935 Uncemeneted open hole liner w/ pre - perforated pup joints 4 1/2 6 12.6 L-80 TXP 6,319 10,600 / 7,903 16,919 / 7,970 Uncemented open hole liner w/ pre - perforated pup joints 7. Diventer System Information (Requirements of20AAC25.005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). M76-05 APD Page 5 of 15 Printed.., 4 -Apr -18 A( ation for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) 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 <]0.0 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. Maintain mud weight from 9.4-10.0 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. Intermediate#2: 7,r ar 1( L.....� Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. 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 10.3 ppg or higher 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 a oil-based mud drill -in fluid VersaPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-05 APD Page 6 of 15 Printed: 4 -Apr -18 Surface Intermediate Intermediate production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0-10.0 9.4-10.0 10.0-11.0 8.8 PV CP 13 10 10 15 YP ib./100 2 35-50 20-28 20-28 15-20 Funnel Viscosity s/qt. 200 40-50 40-50 60-80 Initial Gels lb./100 50 10 10 10 ft2 10 Minute Ib./100 Gels ftz 60 15 20 15 API Fluid cc/30 Loss min. N.C. — 15.0 5.0 5.0 4.0 HPHT Fluid cc/30 n/a 8.0-12.0 8.0-12.0 10.0 Loss min. P" 1 11.0 9.5-10.0 9.5-10.0 9.0-9.5 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 <]0.0 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. Maintain mud weight from 9.4-10.0 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. Intermediate#2: 7,r ar 1( L.....� Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. 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 10.3 ppg or higher 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 a oil-based mud drill -in fluid VersaPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-05 APD Page 6 of 15 Printed: 4 -Apr -18 At 3tion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 9. Abnormally Pressured Formation Information(Requirements of20AAC25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis(Requirements of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20AAC25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20AAC25.005 (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. 124 ter. 1. MIRU Doyon 19 onto MT6-05 over pre-installed 20" insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR). 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. -- 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBR.. 5� 4s 6. Test BOPE to 250 psi low / 3500 psi high (2448 hr. AOGCC notice, 72 hr. BLM notice). 7. Pick up and run in hole with 12-1/4" drilling BHA to drill intermediate # 1. 8. Chart casing pressure test toepsi for 30 minutes. 9. Drill out shoe track and 20' of new hole. i Z- 10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is�pg EMW. 1J. Displace well to 9.4 ppg LSND mud. Drill 12-1/4" hole to the casing point — 8,982ft MD / 7,099ft TVD. (LWD Program: GR/RES). 5 05 13. Circulate wellbore clean and POOH. �/W G,4s k CJ4. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low I WCpsi high. ° A4"sr J �^ 15. Run 9-5/8" intermediate casing or liner, depending on the FIT at surface casing shoe, to TD. Depending on the LOT figure at surface casing shoe, the contingency plan is to run 9-5/8" liner other than long casing string. 16. Pump single stage cement job to isolate the casing shoe or 500' MD or 250' TVD, whichever is larger, above uppermost hydro -carbon bearing zone. YL&_/y 17. Change upper 9-5/8" solid body rams to 3-1/2" x 6" VJ314. Test BOPE to 2503wpsi. 18. Pick up and run in hole with 8-3/4" bit and clean out assembly. Perform a LOT down the 13-3/8" x 9 5/8" casing annulus with Ball mill and freeze protect. .roc 19. Pressure test casing t01341K0 psi for 30 minutes and record results. 20. Drill out shoe track and 20' of new hole. MT6-05 APD Page 7 of 15 Printed: 4 -Apr -18 MT6-05 APD Page 8 of 15 Printed: 4 -Apr -18 i Al nion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW. 22. Circulate wellbore clean and POOH. 23. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly. (L WD Program: GR/RES). 1 24. RIH to bottom with 7" SDL on 5" drill pipe. 25. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). 26. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. 27. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in preparations for cementing. (> R..� ? 28. Cement 7" liner to top of liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying v,lll� down 5" drill pipe. t ' 29. Run 7" tie -back and engage seals. Space out to land hanger. 30. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger and pressure test annulus and seals to 2000 psi for 30 min and chart. M. fT 31. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high. d (� �s 32. Pick up and RIH with 6" drilling assembly. (I "Program: GR/Azimuthal RES). ✓ f ` 33. Chart casing pressure test to(35�00�si for 30 minutes and record results. C'% u F -7 \� 30,1Ps_ .Uz— o (� 34. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.5 ppg EMW. 35. Drill 6" horizontal hole to section TD for the lower C sand lateral. (LWD Program: GR/RES/Sonic for TOC evaluation). 36. Circulate the hole clean and POOH. 37. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe. 38. Set hanger and liner top packer and POOH. . Run and set whipstock system and space out to place window in top Alpine C sand and orient whipstock using T3 MWD. y L 1 r -c5 40. Mill window. rL 1 41. POOH and lay down milling BHA. MT6-05 APD Page 8 of 15 Printed: 4 -Apr -18 At ation for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-05 will be injected into dedicated Class 1 disposal well CDl-01A, ✓ The MT6-05 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1100' TVD. Significant hydrocarbon zones include the Alpine. There will be 500' of cement fill placed above the top of the Alpine reservoir. Once MT6-05 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 (C40). 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) * (2035') + 1,500 psi = 2,770 psi Pore Pressure = 910 psi Therefore Differential = 2770 — 910 = 1860 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 (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC -M 2260 psi 1921 psi 5020 psi 4267 DSI 9-5/8 40 L-80 3 BTC -M 3090 psi 2626 DSI 5750 psi 4887 psi MT6-05 APD Page 9 of 15 Printed. 4 -Apr -18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan Ar ition for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 MT6-05 APD Page 10 of 15 Printed: 4 -Apr -18 Al: tion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 Attachment 1 — Cement Summary MT6-05 wp04 Cementing Program: GMTU MT6-05 wp04 MT6-05 APD Page 11 of 15 Printed: 4 -Apr -18 Al( nion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 13-3/8" Surface Casine run to 2.054' MD / 2,032' TVD. Cement from 2,054' MD to 1,554'(500' of tail) with Class G+ Adds. @ 15.8 PPG, and from 1,554' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,350' MD), zero excess in 20" conductor. Lead slurry from 1,554' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'— 36) X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3 Permafrost to Conductor (1,100'— 1151 X 0.4206 W/ft X 3.5 (250% excess) = 1,450 ft3 Top of Tail to Permafrost (1,554'-1,1001 X 0.4206 ft3/ft X 1.5 (50% excess) = 286 ft3 Total Volume= 81 + 1,450 + 286 = 1,817 ft3 => 942 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,054' MD to 1,554' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,054'-1,554) X 0.4206 ft3/ft X 1.50 (50% excess) = 316 ft' Shoe Joint (80) X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 316 + 68 = 384 ft' => 328sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 9-5/8" Intermediate casing to 8.982' MD / 7.099' TVD Cement 500' up from 9-5/8" casing shoe from 8982' MD to 8482' MD. Assume 40% excess annular volume. Tail slurry from 8,982' MD to 8,482' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (8,982'-8,482) X 0.3132 ft3/ft X 1.40 (40% excess) = 220 ft3 Shoe Joint (80) X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 220 + 34 = 254 ft3 => 216 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 7" Intermediate liner run to 11,000' MD / 7,959' TVD Top of slurry is designed to be at liner top at 8,700' MD. Assume 40% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Tail slung from 11,000' MD to 8,700' MD with 15.8 ppg Class G + additives 8-3/4" Hole to Casing shoe (11,000'— 8,7001 X 0.1503 ft3/ft X 1.40 (40% excess) = 484 ft3 Liner Lap (8,982'— 8,7001 X 0.1503 ft3/ft X 1.0 (0% excess) =42W Shoe Joint (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 191:3 Total Volume = 484+ 42 + 17 = 543 ft3 => 464 sx of 15.8 ppg Class G + 0.2% DG46 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk MT6-05 APD Page 12 of 15 Printed., 4 -Apr -18 Ali lion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" HnIP / racinn Tntarval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and Hole swabbing on trips Medium circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Lost circulation Low Increase mud weight, use weighted sweeps, Abnormal Pressure in Low reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations Medium hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement Abnormal Reservoir Low slurries ort collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casina Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time hole ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD Lost circulation Low monitorinq, MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations connections, increase mud weight. Shallow hazard Hole swabbing on trips Medium study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 6" x R-3/4" Hale / 7" Liner - Casina Tnterval Event Risk Level Mitigation Strate Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-05 APD Page 13 of 15 Printed. 4 -Apr -18 Aj Rion for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control pradices mud scavengers 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: normal original pore pressure is prognosed. Nevertheless, LCM material will be on location to deal with losses. 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 #2 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. MT6-05 APD Page 14 of 15 Printed: 4 -Apr -18 Al ition for Permit to Drill, Well MT6-05 Saved: 4 -Apr -18 Attachment 3 — Completion Schematic (includes Alpine C Upper lateral, as detailed in MT6-051_1 PTD) MT6-05 Multi -lateral Producer, wp04 DRAFT Completion Schematic Top Alpine C 10,823' MO 17937 TVD 20" 79 ppf H40 Insulated Conductor 90 feat vernented to surface kj 1338" 68 ppf L-80 H563 ( Surf to 1204'PW to TD Surrace Casing Q 2054' MD f 2033' TVD cennented in suroce 4 -1t2 -12S ppf L-80 Blue to 10,600' MD 9 58" 40 ppf L40 TXP (o 5847' MD) 9 5t8- 40 ppf TN -80 HC (o TD) @ 8,487 WO J TM9 TVD TOC of 9 V8 - 8.400 ft),ID 1) 4-:<- Landvng Nipple (3.913" 101 2) 4-K_'x V43LM 3) 4-X'x 1'GLM 4) 4-:5'x I' GLM 5) Liner Top Packer 7 Hanger %V Tie Back sdewe 6) LEA and look Hanger 7) Liner Top Paoker 7 Hanger vV TP -Back Skye 8) 4-:S Landing Nipple (3.725' NoGc) 9) 4 %' Blue Blank Pipe 10) 4!'Bkce Linerwith Ped Pups L2 Winnow—Baker Hook Hanger Junction 10.W MD+7P41'TVD -- 4-'n_"t2.6#L-80 Blue Liner 6'lmie, Te at Vth Peri Joints at 16,917•Mn l 7435'TVD a o a o 0 0 0 0 0 1 6:t" 12.6# L-80 Blue liner Q G) 14Nh Pecfjoints !\\ a p ,�•0 0 0 a 0 o O 7- 26 ppf L-80 Tenaris B1ueIH563 Liner w 1 O MD 1-7,959' TVD @ 83 deg 6- Noie, TO at zt 16417 MD/ 7470`TVL1 2j11701d-lISSJBDN MT6-05 APD Page 15 of 15 Printed. 4 -Apr -18 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #5 GMT1-B2 Wellbore #5 Plan: MT6-05-wp04_Lower Lat Directional Summary Report 23 January, 2018 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #5 GMT1-82 Protect: Western North Slope TVD Reference: WELL Q 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL Q 70.00usft (Original Well Elev) Well: Plan: Well #5_GMT1-B2 North Reference: True Wellbore: Wellbore #5 Survey Calculation Method: Minimum Curvature Design: MT6-05-wp04 Lower Let Database: EDTAlaska Prod Project Western North Slope, North Slope Alaska, United States Ground Level: 34.00usft 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 Site Plan'. GMT1 Lookout Pad Plan: Well #5—GMT1-S2 Site Position: Northing: 5,945,316.00 usft Latitude: 70° 15'22.006 N From: Map Easting: 1,457,169.00 usft Longitude: 151' 28'52.049 W '.. ''.. Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: -1.39 ° well Plan: Well #5—GMT1-S2 Well Position +N/ -S 0.00 usft Northing: 5,945,289.00 usft Latitude: 70° 15'21.723 N +E/ -W 0.00 Usti Easing: 1,457.094.00 usft Longitude: 151'28'54.211 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 34.00usft Wellbore Wellbore #5 'j Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2017 6W2018 16.48 8031 57,420 Design MT6-05-wp04_1-ower Let Audit Notes: Version: Phase: PLAN Tie On Depth: 36.00 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction ("aft) (usft) (usft) (*) 36.00 0.00 0.00 320.84 112 3120 18 10:07.26AM Page 2 COMPASS 5000.14 Build 85 1�1 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #5 GMT7-B2 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well #5_GMT1-82 North Reference: True Wellbore: Wellbore #5 Survey Calculation Method: Minimum Curvature Design: MT6-05-wp04_1-ower Let Database: EDT Alaska Prod Survey Tool Program Date 1/23/2018 From TO - lusR) (usft) Survey (Wellbore) Tool Name Description 36.00 300.00 MT6-05-wp04_Lower Lat(Wellbore#5) BLIND Blind drilling 300.00 2,054.00 MT6-05-wp04_Lower Let (WellbOre#5) MWD MWD -Standard 300.00 2,054.00 MT6-05-wp04 Lower Let (Welibore#5) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,054.00 8,982.00 MT6-05-wp04_Lover Let (Wellbore #5) MWD MWD -Standard 2,054.00 8,982.00 MTM&wp04_Lower Let (Wellbore #5) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,982.00 11,000.00 MT6-05-wp04_Lower Let (Wellbore #5) MWD MWD - Standard 8,982.00 11,000.00 MT6.05-wp04_Lower Let (Welftra #5) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,000.00 16,919.00 MT6-05-wp04_Lower Let (Wellbore#5) MWD MWD -Standard 11,000.00 16,919,53 MT6-05-wp04_Lower Let (Wellbore #5) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°/100usft) (•) (usft) (usft) (usft) 36.00 0.00 0.00 36.00 -34.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 100.00 0.00 0.00 100.00 30.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 200.00 0.00 0.00 200.00 130.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 300.00 0.00 0.00 300.00 230.00 0.00 0.00 0.00 5,945,289.00 1,457,094,00 400.00 0.00 0.00 400.00 330.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 500.00 0.00 0.00 500.00 430.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 600.00 0.00 0.00 600.00 530.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 700.00 0.00 0.00 700.00 630.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 800.00 0.00 0.00 800.00 730.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 900.00 0.00 0.00 900.00 830.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 1,000,00 0.00 0.00 1,000.00 930.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 1,036.00 0.00 0.00 1,036.00 966.00 0.00 0.00 0.00 5,945,289.00 1,457,094.00 Start Build 2.00 1,100.00 1.28 306.00 1,099.99 1,029.99 2.00 306.00 0.69 5,945,289.43 1,457,093.43 1,200.00 3.28 306.00 1,199.91 1,129.91 2.00 0.00 4.54 5,945,291.85 1,457,090.27 1,300.00 5.28 306.00 1,299.63 1,229.63 2.00 0.00 11.75 5,945,296.38 1,457,064,34 123/2018 10:07r26AM Page 3 COMPASS 500014 Build 65 ConocoPhillips Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plam GMT1 Lookout Pad Well: Plan: Well #5GMTI-B2 Wellbore: Wellbore#5 Design: MT6-05-wp04_Lower Let ConocoPhillips Directional Summary Report Local Co-ordinate Reference: Well Plan: Well #5_GMT7-B2 Planned Survey WELL Q 70.00usft (Original Well Elev) MD Inc WELL @ 70.00usft (Original Well Elev) (usft) 1°I True 1,400,00 7.28 1,500.00 9.28 1,600.00 11.28 1,700.00 13.28 1,800.00 15.28 1,900.00 17.28 2,000.00 19.28 2,040.45 20.09 Start 80.00 hold at 2040AS MD 2,054.00 20.09 13-318" z 16" 0.00 2,100.00 20.09 2,120.45 20.09 Start DLS 2.00 TFO -0.04 1,526.36 2,123.56 20.15 C-30 5,945,322.61 2,200.00 21.68 2,300.00 23.68 2,400.00 25.68 2,500.00 27.68 2,514.34 27.97 C-10 1,720.98 2,600.00 29.68 2,700.00 31.68 2,800.00 33.68 2,900.00 35.68 3,000.00 37.68 3,100.00 39.68 ConocoPhillips Directional Summary Report Local Co-ordinate Reference: Well Plan: Well #5_GMT7-B2 TVD Reference: WELL Q 70.00usft (Original Well Elev) MD Reference: WELL @ 70.00usft (Original Well Elev) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Prod Azi(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (°) (usft) (usft) (°1100usft) ,,. (°) (usft) (usft) -(usft) 306.00 1,399.02 1,329.02 2.00 0.00 22.32 5,945,303.02 1,457,075.65 306.00 1,497.97 1,427.97 2.00 0.00 36.24 5,945,311.77 1,457,064.21 306.00 1,596.36 1,526.36 2.00 0.00 53.49 5,945,322.61 1,457,050.04 306.00 1,694.07 1,624.07 2.00 0.00 74.05 5,945,335.52 1,457,033.14 306.00 1,790.98 1,720.98 2.00 0.00 97.89 5,945,350.50 1,457,013.55 306.00 1,886.96 1,816.96 2.00 0.00 124.99 5,945,367.52 1,456,991.28 306.00 1,981.91 1,911.91 2.00 0.00 155.31 5,945,386.57 1,456,966.36 306.00 2,020.00 1,950.00 2.00 0.00 168.48 5,945,394.84 1,456,955.54 306.00 2,032.72 1,962.72 0.00 0.00 172.98 5,945,397.67 1,456,951.84 306.00 2,075.92 2,005.92 0.00 0.00 188.25 5.945,407.26 1,456,939.29 306.00 2,095.13 2,025.13 0.00 0.00 195.04 5,945,411.53 1,456,933.71 306.00 2,098.05 2,028.05 2.00 -0.04 196.08 5,945,412.18 1,456,932.86 306.00 2.169.45 2,099.45 2.00 -0.04 222.45 5,945,428.75 1,456,911.18 305.99 2,261.71 2,191.71 2.00 -0.04 259.72 5,945,452.16 1,456,880.55 305.99 2,352.57 2,282.57 2.00 -0.03 300.08 5,945,477.51 1,456,847.38 305.99 2,441.92 2,371.92 2.00 -0.03 343.48 5,945,504.77 1,456,811.70 305.99 2,454.60 2,384.60 2.00 -0.03 349.95 5,945,508.83 1,456,806.39 305.99 2,529.65 2,459.65 2.00 -0.03 389.87 5,945,533.90 1,456,773.57 305.98 2,615.65 2,545.65 2.00 -0.03 439.18 5,945,564.88 1,456,733.03 305.98 2,699.81 2,629.81 2.00 -0.03 491.37 5,945,597.65 1,456,690.13 305.98 2,782.04 2,712.04 2.00 -0.02 546.36 5,945,632.19 1,456,644.92 305.98 2,862.24 2,792.24 2.00 -0.02 604.10 5,945,668.45 1,456,597.46 305.98 2,940.30 2,870.30 2.00 -0.02 664.50 5,945,706.38 1,456.547.80 112312018 10:07:26AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #5_GMT1-B2 Wellborn: Wellbore #5 Design: MT6-05-wp04 lower Lot ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #5 GMT1-B2 WELL @ 70.00usft (Original Well Eley WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDTAlaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (1) (°) (usR) (usft) (*1100usft) V) (usR (usft) (usft) 3,200,00 41.68 305.98 3,016.13 2,946.13 2.00 -0.02 727.50 5,945,745.94 1,456,496.00 3,300.00 43.68 305.98 3,069.64 3,019.64 2.00 -0.02 793.02 5,945,787.08 1,456,442.13 3,372,40 45.13 305.98 3,141.37 3,071.37 2.00 -0.02 841.98 5,945,817.83 1,456,401.87 Start 5950.00 hold at 3372.40 MD 3,400.00 45.13 305.98 3,160.64 3,090.84 0.00 0.00 860.89 5,945,829.70 1,456,386.33 3,500.00 45.13 305.98 3,231.39 3,161.39 0.00 0.00 929.38 5,945,872.71 1,456,330.01 3,600.00 45.13 305.98 3,301.94 3,231.94 0.00 0.00 997.88 5,945,915.73 1,456,273.70 3,700.00 45.13 305.98 3,372.49 3,302.49 0.00 0.00 1,066.38 5,945,958.74 1,456,217.38 3,739.65 45.13 305.98 3,400.47 3,330.47 0.00 0.00 1,093.54 5,945,975.79 1,456,195.05 K-3 3,000.00 45.13 305.98 3,443.05 3,373.05 0.00 0.00 1,134.87 5,946,001.75 1,456,161.06 3,900.00 45.13 305.98 3,513.60 3,443.60 0.00 0.00 1,203.37 5,946,044.76 1,456,104.74 4,000.00 45.13 305.98 3,584.15 3,514.15 0.00 0.00 1,271.87 5,946,087.78 1,456,048.43 4,100.00 45.13 305.98 3,654.70 3,584.70 0.00 0.00 1,340.37 5,946,130.79 1,455,992.11 4,200.00 45.13 305.98 3,725.26 3,655,26 0.00 0.00 1,406.86 5,946,173,80 1,455,93579 4,300.00 45.13 305.9(5 3,795.81 3,725.81 0.00 0.00 1,477.36 5,946,216.81 1,455,879.47 4,400.00 45.13 305.98 3,866.36 3,796.36 0.00 0.00 1,545.86 5,946,259.83 1,455,823.16 4,475.69 45.13 305.98 3,919.76 3,849.76 0.00 0.00 1,597.70 5,946,292.38 1,455,780.53 Alblan 97 4,500.00 45.13 305.98 3,936.91 3,666.91 0.00 0.00 1,614.35 5,946,302.84 1,455,766.84 4,600.00 45.13 305.98 4,007.47 3,937.47 0.00 0.00 1,682.85 5,946,345.85 1,455,710.52 4,700.00 45.13 305.98 4,078.02 4,008.02 0.00 0.00 1,751.35 5,946,388.86 1,455,654.20 4,800.00 45.13 305.98 4,148.57 4,078.57 0.00 0.00 1,819.85 5,946,431.88 1,455,597.89 4,848.87 45.13 305.98 4,162.91 4,112.91 0.00 0.00 1,853.18 5,946,452.81 1,455,570.48 Alblan 96 4,900.00 45.13 305.98 4,219.12 4,149.12 0.00 0.00 1,888.34 5,946,474.89 1,455,541.57 5,000.00 45.13 305.98 4,289.68 4,219,68 0.00 0.00 1,956,84 5,946,517.90 1,455,485.25 1232018 10:07:26AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConamPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: Well #5 GMT11-82 Project: Western North Slope TVD Reference: WELL @ 70.00usft (Original Well Elev) Site: Plan: GMT1 Lookout Pad MD Reference: WELL @ 70.00usft (Original Well Elev) Well: Plan: Well#5_GMT1-B2 North Reference: True Wellbore: Wellbore #5 Survey Calculation Method: Minimum Curvature Design: MT6-05-wp04 Lower Let Database: EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 5,100.00 45.13 305.98 4.360.23 4,290.23 0.00 0.00 2,025.34 5.946,560.91 1,455,428.93 5,200.00 45.13 305.98 4,430.78 4,360.78 0.00 0.00 2,093.83 5,946,603.93 1,455,372.62 5,300.00 45.13 305.98 4,501.33 4,431.33 0.00 0.00 2,162.33 5,946,646.94 1,455,316.30 5,320.90 45.13 305.98 4,516.08 4,446.08 0.00 0.00 2,176.65 5,946,655.93 1,455,304,53 Albion 96 5,400.00 45.13 305.98 4,571.89 4,501.89 0.00 0.00 2,230.83 5,946,689.95 1,455,259.98 5,500.00 45.13 305.98 4,642.44 4,572.44 0.00 0.00 2,299.32 5,946,732.96 1,455,203.67 5,600.00 45.13 305.96 4,712.99 4,642,99 0.00 0.00 2,367.62 5,946,775.98 1,455,147.35 5,700.00 45.13 305.98 4,783.54 4,713.54 0.00 0.00 2,436.32 5,946,818.99 1,455,091.03 5,800.00 45.13 305.98 4,854.10 4,764.10 0.00 0.00 2,504.82 5,946,662.00 1,455,034.71 5,900.00 45.13 305.98 4,924.65 4,854.65 0.00 0.00 2,573.31 5,946,905.01 1,454,978.40 6,000DD 45.13 305.98 4,995.20 4,925.20 0.00 0.00 2,641.81 5,946,948.03 1,454,922.08 6,100.00 45.13 305.98 5,065.75 4,995.75 0.00 0.00 2,710.31 5,946,991.04 1,454,865.76 6,200.00 45.13 305.98 5,136.31 5,066.31 0.00 0.00 2178,80 5,947,034.05 1,454,809.44 6,300.00 45.13 305.98 5,206.86 5,136.86 0.00 0.00 2,847.30 5,947,077.06 1,454,753.13 6,400.00 45.13 305.98 5,277.41 5,207.41 0.00 0.00 2,915.60 5,947,120.08 1,454,696.81 6,500.00 45.13 305.98 5,347.96 5,277.96 0.00 0.00 2,964.29 5,947,163.09 1,454,640.49 6,600.00 45.13 305.98 5,418.52 5,348.52 0.00 0.00 .3,052.79 5,947,206.10 1,454,584.17 6,700.00 45.13 305.98 5,489.07 5,419.07 0.00 0.00 3,121.29 5,947,249.11 1,454,527.86 6,800.00 45.13 305.98 5,559.62 5,489.62 0.00 0.00 3,189.79 5,947,292.13 1,454,471.54 6,900.00 45.13 305.98 5,630.17 5,560.17 0.00 0.00 3,256.28 5,947,335.14 1,454,415.22 7,000.00 45.13 305.98 5,700.72 5,630.72 0.00 0.00 3,326.78 5,947,378.15 1,454,358.90 7,075.81 45.13 305.98 5,754.21 5,664.21 0.00 0.00 3,378.71 5,947,410.76 1,454,316.21 Albion 94 7,100.00 45.13 305.98 5,771.28 5,701.28 0.00 0.00 3,395.28 5,947,421.16 1,454,302.59 7,200.00 45.13 305.98 5,641.83 5,771.63 0.00 0.00 3,463.77 5,947,454.18 1,454,246.27 7,300.00 45.13 305.98 5,912.38 5,642.38 0.00 0.00 3,532.27 5,947,507.19 1.454.189.95 1/232018 10:07:26AM Page 6 COMPASS 5000.14 Build 65 ConocoPhillips Company: ConomPhiliips(Alaska) Inc.-WNS Project: Western North Slope Site: Pian: GMT1 Lookout Pad Well: Plan: Mil #5GMT7-B2 Wellbore: Wellbore #5 Design: MT6-05-wp04 Lower Let Planned Survey MD (usft) 7,400.00 7,500.00 7,600.00 7,683.44 Ablian 93 7,700.00 7,800.00 7,900.00 6,000.00 8,100.00 8,200.00 8,279.11 Top FIII 8,300.00 8,400.00 8,500.00 8,600.00 8,700.00 8,800.00 6,900.00 8,981.85 HRZ Slump 8,981.90 9-618" x 12.1W' 9,000.00 9,100.00 9,200.00 9,300.00 ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #5_GMT1-132 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Inc Azi(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easdng (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 45.13 305.98 5,982.93 5,912.93 0.00 0.00 3,600.77 5,947,550.20 1,454,133.63 -x 45.13 305.98 6,053.49 5,983.49 0.00 0.00 3,669,27 5,947,593.21 1,454,077.32 45.13 305.98 6,124.04 6,054.04 0.00 0.00 3,737.76 5,947,636.23 1,454,021.00 45.13 305.98 6,182.91 6,112.91 0.00 0.00 3,794.92 5,947,672.12 1,453,974.01 45.13 305.98 6,194.59 6,124.59 0.00 0.00 3,806.26 5,947,679.24 1,453,964.68 45.13 305.98 6,265.14 6,195.14 0.00 0.00 3,874.76 5,947,722.25 1,453,908.36 45.13 305.98 6,335.70 6,265.70 0.00 0.00 3,943.25 5,947,765.26 1,453,652.05 45.13 305.98 6,406.25 6,336.25 0.00 0.00 4,011.75 5,947,808.28 1,453,795.73 45.13 305.98 6,476.80 6,406.80 0.00 0.00 4,080.25 5,947,851.29 1,453,739.41 45.13 305.98 6,547.35 6,477.35 0.00 0.00 4,148.74 5,947,894.30 1,453,683.09 45.13 305.98 6,803.17 6,533.17 0.00 0.00 4,202.93 5,947,928.33 1,453,638.54 45.13 305.98 6,617.91 6,547.91 0.00 0.00 4,217.24 5,947,937.31 1,453,626.78 45.13 305.98 6,688.46 6,618.46 0.00 0.00 4,285.74 5,947,980.33 1,453,570.46 45.13 305.98 6,759.01 6,689.01 0.00 0.00 4,354.24 5,948,023.34 1,453,514.14 45.13 305.98 6,829.56 6,759.56 0.00 0.00 4,422.73 5,948,066.35 1,453,457.82 45.13 305.98 6,900.12 6,830.12 0.00 0.00 4,491.23 5,948,109.36 1,453,401.51 45.13 305.98 6,970,67 6,900.67 0.00 0.00 4,559.73 5,948,152.38 1,453,345.19 45.13 305.98 7,041.22 6,971.22 0.00 0.00 4,628.22 5,948,195.39 1,453,288.87 45.13 305.98 7,098.97 7,028,97 0.00 0.00 4,684.29 5,948,230.60 1,453,242.77 45.13 305.98 7,099.00 7,029.00 0.00 0.00 4,684.32 5,948,230.61 1,453,242.75 45.13 305.98 7,111.77 7,041.77 0.00 0.00 4,696.72 5,948,236.40 1,453,232.55 45.13 305.98 7,182.33 7,112.33 D.00 0.00 4,765.22 5,948,281.41 1,453178.24 45.13 305.98 7,252.88 7,182.88 0.00 0.00 4,833.72 5,948,324.43 1,453,119.92 45.13 305.98 7,323.43 7,253.43 0.00 0.00 4,902.21 5,948,367.44 1,453,063.60 123/2018 10:07.26AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #5_GMT1-82 Wellbore: Wellbore #5 Design: MT645-wp04_Lower Let Planned Survey MD Inc TVD (usft) (°) DLeg 9,322.40 45.13 Start DLS 3.60 TFO 33.93 Easting 9,400.00 47.40 9,452.79 48.97 LCU (usft) 9,500.00 50.38 9,600.00 53.40 9,700.00 56.47 9,800.00 59.56 9,900.00 62.69 10,000.00 65.83 10,100.00 68.99 10,185.41 71.07 Start 101.23 hold at 10166.41 MD 10,200.00 71.07 10,266.63 71.07 Start DLS 3.05 TFO 41.56 32.50 10,300.00 71.83 10,400.00 74.14 10,500.00 76.46 10,600.00 78.80 10,700.00 81.15 10,770.42 82.81 Start 80.00 hold at 10770.42 MD 10,800.00 82.81 10,826.45 82.81 ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #S GMT1-82 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (11410 305.96 7,339.24 7,269.24 0.00 0.00 4,917.56 5,948,377.08 1,453,050.98 308.04 7,392.88 7,322.88 3.50 33.93 4,971.99 5,948,411.91 1,453,007.07 309.35 7,428.08 7,358.08 3.50 32.50 5,010.46 5,948,437.24 1,452,976,97 310.48 7.458.63 7,388.63 3.50 31.63 5,045.79 5,948,461.00 1,452,949.94 312.71 7,520.34 7,450.34 3.50 30.90 5,123.44 5,948,514.66 1,452,892.43 314.78 7,577.79 7,507.79 3.50 29.52 5,204.65 5,946,572.69 1,452,834.73 316.71 7,630.76 7,580.76 3.50 28.33 5,289.12 5,948,634.86 1,452,777.07 318.51 7,679.04 7,609.04 3.50 27.31 5,376.54 5,948,700.95 1,452,719.65 320.22 7,722.47 7,652.47 3.50 26.43 5,466.57 5,948,770.71 1,452,662.70 321.84 7,760.88 7,690.88 3.50 25.89 5,558.88 5,948,843,88 1,452,606.43 322.87 7,783.22 7,713.22 3.50 25.07 5,620.33 5,948,893.46 1,452,570.08 322.87 7,794.44 7,724.44 0.00 0.00 5,653.03 5,948,920.01 1,452,550.98 322.87 7,816.06 7,746.06 0.00 0.00 5,716.02 5.940,971.17 1,452,514.17 323.58 7,826.67 7,756.67 3.05 41.56 5,747.62 5,948,996.96 1,452,495.85 325.68 7,855.93 7,785.93 3.05 41.33 5,843.02 5,949,076.25 1,452,442.43 327.72 7,881.32 7,811.32 3.05 40,72 5,939.23 5.949,158.35 1,452,391.33 329.73 7.902.75 7,832.75 3.05 40.20 6,035.97 5,949,243.03 1,452,342.68 331.70 7,920.16 7,850.16 3.05 39.77 6,132.97 5,949,330.05 1,452,296.64 333.08 7,929.99 7,859.99 3.05 39.42 6,201.29 5,949,392.61 1,452,265.84 333.08 7,933.69 7.863.69 0.00 0.00 6,229.97 5,949,419.09 1,452.253.20 333.08 7,937,00 7,867.00 0.00 0.00 6,255.62 5,949,442.77 1,452,241.89 1/23/2018 10:07:26AM Page 8 COMPASS 5000.14 Build 65 ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Wali: Plan: Well #5_GMT1-B2 Wellbore: Wellbore #5 Design: MTB-05-wp04_Lower Lat ConocoPhillips Directional Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #5 GMT1-B2 WELL C 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Seating (usft) (') (1 (usft) (usft) (°1100usft) (°) (usft) (usft) (waft) 10,850.42 82.81 333.08 7,940.00 7,870.00 0.00 0.00 6,278.86 5,949,464.23 1,452,231.64 Start 200.00 hold at 10860,42 MD 10,900.00 82.81 333.06 7,946.20 7,876.20 0.00 0.00 6,326.92 5,949,508.61 1,452,210.45 11,000.00 82.81 333.08 7,958.72 7,888.72 0.00 0.00 6,423.88 5,949,598.14 1,452,167,70 7" x 9.314" 11,050.42 82.81 333.08 7,965.03 7,895,03 0.00 0.00 6,472.77 5,949,643.28 1,452,146.14 Start DLS 3.73 TFO 4.09 11,100.00 84.66 333.04 7,970.44 7,900,44 3.73 -1.09 6,520.93 5,949,687.74 1,452,124,89 11,162.69 87.00 333.00 7,975.00 7,905.00 3.73 -1.09 6,582.05 5,949,744.13 1,452,097.90 Start DLS 4.00 TFO 1.63 11,200.00 86.49 333.04 7,976.47 7,906.47 4.00 1.63 6,618.49 5,949,777.75 1,452,081,80 11,239.48 90.07 333.09 7,976.96 7,906.96 4.00 1.63 6,657.07 5,949,813,36 1,452,06478 Start 6680.05 hold at 11239.48 MD 11,300.00 90.07 333.09 7,976.89 7,906.89 0.00 0.00 6,716.21 5,949,867.98 1,452,038.71 11,400.00 90,07 333.09 7,976.77 7,906.77 0.00 0.00 6,813.93 5,949,958.22 1,451,995.64 11,500.00 90.07 333.09 7,976.64 7,906,64 0.00 0.00 6,911.66 5,950,048.45 1,451,952.56 11,600,00 90.07 333.09 7,976.52 7,906.52 0.00 0.00 7,009.38 5,950,138.69 1,451,909.48 11,700.00 90.07 333.09 7,976.40 7,906.40 0.00 0.00 7,107.11 5,950,228.93 1,451,866.40 11,800.00 90.07 333.09 7,976.28 7,906.28 0.00 0.00 7,204.83 5,950,319.17 1,451,823.33 11,900.00 90.07 333.09 7,976.15 7,906.15 0.00 0.00 7,302.55 5,850,409.41 1,451,780.25 12,000.00 90.07 333.09 7,976.03 7,906.03 0.00 0.00 7,400,28 5,950,499.85 1,451,737,17 12,100.00 90.07 333.09 7,975.91 7,905.91 0.00 0.00 7,498.00 5,950,589.89 1,451,694.10 12,200.00 90.07 333.09 7,975.79 7,905.79 0.00 0.00 7,595.73 5,950,680.13 1,451,651.02 12,300.00 90.07 333.09 7,975.66 7,905,66 0.00 0.00 7,693.45 5,950,770.37 1,451,607.94 12,400,00 90.07 333.09 7,875.54 7,905.54 0,00 0.00 7,791.18 5,950,860.61 1,451,584.87 l 12,500.00 90.07 333.09 7,975.42 7,905.42 0.00 0.00 7,888.90 5,950,950.85 1,451,521.79 12,800.00 90.07 333.09 7,975.29 7,905.29 0,00 0.00 7,986.62 5,951.041.09 1,451,478.71 12,700.00 90.07 333.09 7,975.17 7,905.17 0.00 0.00 8,084.35 5,951,131.33 1,451,435.64 V232018 10:07:26AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips Company: Project: Site: Well: Wellbore: Design: Planned Survey MD (usft) ConocoPhilhps(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: Well #S GMT1-B2 Wellbore #5 MT6-05-wp04 Lower Let 12,600.00 12,900.00 13,000.00 13,100.00 13,200.00 13,300.00 13,400.00 13.500.00 13,600.00 13,700.00 13,800.00 13,900.00 14,000.00 14,100.00 14,200.00 14,300.00 14,400.00 14,500.00 14,600.00 14,700.00 14,800.00 14,900.00 15,000.00 15,100.00 15,200.00 15.300.00 15,400.00 ConocoPhillips Directional Summary Report Local Corordinate Reference: Well Plan: Well #5_GMT1-B2 TVD Reference: WELL @ 70.00usft (Original Well Elev) MD Reference: WELL C 70.00usft (Original Well Elev) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Prod Inc Azi (azimuth) TVD TVDSS DLeg TPace V. Sec Northing Easting (°) (°) (usft) (usft) (°1100usft) (') (usft) (usft) (usft) 90.07 333.09 7,975.05 7,905.05 0.00 0.00 8,182.07 5,951,221.57 1,451,392.56 90.07 333.09 7,974.93 7,904.93 0.00 0.00 8,279.80 5,951,311.81 1,451,349.48 90.07 333.09 7,974.80 7,9D4.80 0.00 0.00 8,377.52 5,951,402.04 1,451,306.41 90.07 333.09 7,974.68 7,904.68 0.00 0.00 8,475.24 5,951,492.28 1,451,263.33 90.07 333.09 7,974.56 7,904.56 0.00 0.00 8,572.97 5,951,582.52 1,451,220.25 90.07 333.09 7,974.44 7,904.44 0.00 0.00 8,670.69 5,951,672.76 1,451,177.18 90.07 333.09 7,974.31 7,904.31 0.00 0.00 8,768.42 5,951,763.00 1,451,134.10 90.07 333.09 7,974.19 7,904.19 0.00 0.00 8,866.14 5,951,853.24 1,451,091.02 90.07 333.09 7,974.07 7,904.07 D.00 0.00 8,963.87 5,951,943.48 1,451,047.95 90.07 333.09 7,973.95 7,903,95 0.00 0.00 9,061.59 5,952,033.72 1,451,004.87 9D.07 333.09 7,973.82 7,903.82 0.00 0.00 9,159.31 5,952,123.96 1,450,961.79 90.07 333.09 7,973.70 7,903.70 0.00 0.00 9,257.04 5,952,214.20 1,450,918.72 90.07 333.09 7,973.58 7,903.58 0.00 0.00 9,354.76 5,952,304.44 1,450,875.64 90.07 333.09 7,973.46 7,903.46 0.00 0.00 9,452.49 5,952,394,68 1,450,832.56 90.07 333.09 7,973.33 7,903.33 0.00 0.00 9,550.21 5,952,484.92 1,450,789.49 90.07 333.09 7,973.21 7,903.21 0.00 0.00 9,647.93 5,952,575.16 1,450,746.41 90.07 333.09 7,973.09 7,903.09 0.00 0.00 9,745.66 5,952,665.40 1,450,703.33 90.07 333.09 7,972.97 7,902.97 0.00 0.00 9,843.38 5,952,755.63 1,450,660.25 90.07 333.09 7,972.84 7,902.84 0.00 0.00 9,941.11 5,952,845.87 1,450,617.18 90.07 333.09 7,972.72 7,902.72 0.00 0.00 10,038.83 5,952,936.11 1,450,574.10 90.07 333.D9 7,972.60 7,902.60 0.00 0.00 10,136.56 5,953,026.35 1,450,531.02 90.07 333.09 7,972.48 7,902.48 0.00 0.00 10,234.28 5,953,116.59 1,450,487.95 90.07 333.09 7,972.35 7,902.35 0.00 0.00 10,332.00 5,953,206.83 1,450,444.87 90.07 333.09 7,972.23 7,902.23 0.00 0.00 10,429.73 5,953,297.07 1,450,401.79 90.07 333.09 7,972.11 7,902.11 0.00 0.00 10,527.45 5,953,387.31 1,450,358.72 90.07 333.09 7,971.99 7,901.99 0.00 0.00 10,625.18 5,953,477.55 1,450,315.64 90.07 333.09 7,971.86 7,901.86 0.00 0.00 10,722.90 5,953,567.79 1,450,272.56 123/2018 10:07:26AM Page 10 COMPASS 5000.14 Build 65 ConocoPhillips ConocoPhillips Directional Summary Report Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well#5_GMT1.82 Wellbore: Wellbore #5 Design: MT6.05-wp04_Lower Let Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: Well #5_GMT1-B2 WELL @ 70.00usft (Original Well Elev) WELL @ 70.00usft (Original Well Elev) True Minimum Curvature EDT Alaska Prod Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TPace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°i100usft (°) (usft) (usft} tusftl 15,500.00 90.07 333.09 7,971.74 7,901.74 0,00 0.00 10,820.62 5,953,658.03 ..,. 1,450,229.49 15.600,00 90.07 333.09 7,971.62 7,901.62 0.00 0,00 10,918,35 5,953,748.27 1,450,186.41 15,700.00 90.07 333.09 7,971.49 7,901.49 0.00 0.00 11,016.07 5,953,838.51 1,450,143.33 15,800.00 90.07 333.09 7,971.37 7,901.37 0.00 0.00 11,113.80 5,953,928.75 1,450,100.26 15,900.00 90.07 333.09 7,971.25 7,901.25 0.00 0.00 11,211,52 5,954,018.99 1,450,057.18 16,000.00 90.07 333.09 7,971.13 7,901.13 0.00 0.00 11,309.25 5,954,109.22 1,450,014.10 16,100.00 90.07 333.09 7,971.00 7,901.00 0.00 0.00 11,406.97 5,954,199.46 1,449,971.03 16,200.00 90.07 333.09 7,970.88 7,900.88 0.00 0.00 11,504.69 5,954,289.70 1,449,927.95 16,300.00 90.07 333.09 7,970.76 7,900.76 0.00 0.00 11,602.42 5,954,379.94 1,449,884.87 16,400,00 90.07 333.09 7,970.64 7,900,64 0,00 0.00 11,700.14 5,954,470.18 1,449,841,80 16,500.00 90.07 333.09 7,970.51 7,900.51 0.00 0.00 11,797.87 5,954,560.42 1,449,798.72 16,600.00 90.07 333.09 7,970.39 7,900.39 0.00 0.00 11,895.59 5,954,650.66 1,449,755.64 16,700.00 90.07 333.09 7,970.27 7,900.27 0.00 0.00 11,993.31 5,954,740.90 1,449,712.57 16,800,00 90,07 333.09 7,970.15 7,900.15 0.00 0.00 12,091.04 5,954,831.14 1,449,669.49 16,900.00 90.07 333.09 7,970.02 7,900.02 0.00 0.00 12,188.76 5,954,921.38 1,449,626.41 16,919.53 90.07 333.09 7,970.00 7,900.00 0.00 0.00 12,207.85 5,954,939.00 1,449,618.00 TD at 16919.63 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 16,919.53 7,970.00 4-1/2"x6" 4-1/2 6 2,054.00 2,032.72 13-3/8" x 16" 13-3/8 16 11,000,00 7,958.72 7"x8-3/4" 7 B-314 8,981.90 7,089.00 M/8"x12-1/4" 9-5/8 12-1,14 123/2018 10:07:264M Page 11 COMPASS 5000.14 Build 85 ConocoPhillips Company: ConocoPhilhps(Alaska) Inc. -WNS Project: Western North Slope Site: Plan: GMT1 Lookout Pad Well: Plan: Well #5_GMTt-B2 Wellbore: Wellbore #5 Design: MT6-05-wp04_Lower Let Formations ConocoPhillips Directional Summary Report Measured Vertical Depth Depth ..�.., .,,. (usft) (usft) Name Lithology 7,075.81 5,754.21 Albian 94 2,514.34 2,454.60 C-10 8,981.85 7,098.97 HRZ Slump j 7,683.44 6,182.91 Ablian 93 5,320.90 4,516.08 Albian 95 3,739.65 3,400.47 K-3 8,279.11 6,603.17 Top Fill 2,123.56 2,098.05 C-30 10,826.45 7,937.00 Alpine C 9,452.79 7,428.08 LCU 4,848.87 4,182.91 Albian 96 4,475.69 3,919.76 Albian 97 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W .*x'. tusitj (usft) (usft) Comment 1,036.00 i 1,036.00 0.00 0.00 Start Build 2.00 2,040.45 2,020.00 102.45 -141.01 Start 80.00 hold at 2040.45 MD 2,120.45 2,095.13 118.60 -163.24 Start DLS 2.00 TFO -0.04 3,372.40 3,141.37 511.86 -704.64 Start 5950.00 hold at 3372.40 MD 9,322.40 7,339.24 2,988.94 4,117.24 Start DLS 3.50 TFO 33.93 10,165.41 7,763.22 3,493.49 4,610.59 Start 101.23 hold at 10165.41 MD 10,266.63 7,816.06 3,569.83 -4,668.39 Start DLS 3.05 TFO 41.56 10,770.42 7,929.99 3,985.13 -4,926.91 Start 80.00 hold at 10770.42 MD 10,850.42 7,940.00 4,055.90 -4,962.85 Start 200.00 hold at 10850.42 MD 11,050.42 7,965.03 4,232.82 -5,052.69 Start DLS 3.73 TFO-1.09 11,162.69 7,975.00 4,332.47 -5,103.37 Start DLS 4.00 TFO 1.63 11,239.48 7,976.96 4,400.89 -5,138.17 Start 5680.05 hold at 11239.48 MD 16,919.53 7,970.00 9,465.77 -7,709.14 TD at 16919.53 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Dip Dip Direction Well Plan: Well #5 GMT1-B2 WELL @ 70.00usf1(Original Well Elev) WELL Q 70.00usft (Original Well Elev) True Minimum Curvature EDTAlaska Prod 123/2018 10:07:26AM Page 12 COMPASS 5000.14 Build 85 005E OSLL 0 I �I i I I I I 000 ,.9L x .9/E -C 000ZL I OOM I 00001 I 0006 I (ul/usn OOOZ) en-OZE 1e uogoaS leopjan 0009 0OOL 0009 0009 0004 I I i t II I 000E I 000z 0001 0 I I I :a}IS adolS WON wafsaM :foafad 0 auidry , a o po p06 O �.4/E-8 x .d y , 3 � ,.9 X..M-4 000 O O 00 o .9/1-21 x..M-6 3 000 O N pp0 4 � m W p� O � 000 M ooOZ m ..9L x ,.B/E•El a (uyusn 0096) (+)lse3/(-)3saM OSLt- 0056- 0925- 000L- ..4/t -U ,9/E-8 x„L ,ea ____ Al .9x uza-4 0 c 5 z 0 mot ;el JaMo-I todM-90-91W :u6lsaa 9# ejoglleM :ajoglleM Z8-L1WJ 9# IIaM :Ueld :IIaM Ped;noNool L1WJ :veld :a}IS adolS WON wafsaM :foafad N N m sdllliLlljoaouoD ConocoPhillips(Alaska) Inc. -WNS Western North Slope Plan: GMT1 Lookout Pad Plan: MT6-05 MT6-05 MT6-05-wp04_Lower Lat ConocoPhillips Clearance Summary Anticollision Report 12 April, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-OS - MT6-05 - MT6-05-wp04_Lower Let Well Coordinates: 5,945,288.65 N, 1,457,094.47 E (70° 15' 21.72" N, 151° 28'54.20" W) Datum Height: WELL @ 70.00usft (Original Well Elev) Scan Range: 0.00 to 16,920.06 usft. Measured Depth. Scan Radius is 1,888.41 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED. All wellpaths within 200'+ 10011000 of reference Scan Type: 2500 ConocoPhillips s �-0 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: MT6-05 - MT6-05-wp04_Lower Lat Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-05 -MT6-05 - MTS-06-wp(14 Lower Let Scan Range: 0.00 to 16,920.06 usft. Measured Depth. Scan Radius is 1,868.41 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: GMT1 Lookout Pad Lookout 1 - Lookout i - Lookout 1 12,820.99 1,325.50 12,820.99 1,105.50 7,975.00 6.025 Clearance Factor Pass - Major Risk MT6-03-MT6-03-MT6-03 wp05 1,031.30 40.00 1,031.30 2.13 1,050.00 1.056 Centre Distance Pass - Major Risk MT6-03-MT6-03-MT6-03 wp05 1,056.15 40.07 1,056.15 1.93 1,075.00 1.051 Clearance Factor Pass - Major Risk MT6-03 - MT6-03 - MT6-03 930.38 35.44 930.38 9.85 950.00 1.385 Centre Distance Pass - Major Risk MT6-03 - MT6-03 - MT6-03 1,030.33 35.87 1,030.33 9.00 1,050.00 1.335 Clearance Factor Pass - Major Risk MT6-03 - MT6-03PB1 - MT6-03PB1 930.38 35.44 930.38 9.85 950.00 1.385 Centre Distance Pass - Major Risk MTB -03 - MT6-03PB1 - MT6-03PB1 1,030.33 35.87 1,030.33 9.00 1,050.00 1.335 Clearance Factor Pass- Major Risk MTB-03-MT6-03PB1-MT6-03PB1 wp05 1,D31.30 40.00 1,031.30 2.13 1,050.00 1.056 Centre Distance Pass - Major Risk MT6-03 - MT6-03PB1 - MT6-03PB1 wp05 1,056.15 40.07 1,056.15 1.93 1,075.00 1.051 Clearance Factor Pass - Major Risk Plan: MT6-01 - MTS -01 - F-wp02 1,025.00 79.98 1,025.00 52.00 1,025.00 2.859 Centre Distance Pass - Major Risk Plan: MT6-01 - MT6-01 - F-wp02 1,049.79 80.02 1,049.79 51.76 1,050.00 2.832 Clearance Factor Pass- Major Risk Plan: MT6-02-MT6-02-E-wp02 1,025.00 60.06 1.025.00 32.08 1,025.00 2.147 Centre Distance Pass - Major Risk Plan: MT6-02 - MT6-02 - E-wp02 1,099.28 60.44 1,099.28 31.55 1,100.00 2.092 Clearance Factor Pass - Major Risk Plan: MT6-04-MT6-04-C1-wp02 ® ® - Plan: MT6-04 - MT6-04 - CI-wp02 ® - Plan: MT6-05-MT6-05_Upper Let -MT6-05-wp04 11,17551 28.51 11,175.51 24.77 11,175.00 7.612 Centre Distance Pass - Major Risk Plan: MT6-05 - MT6-05_Upper Let - MT6-05-wp04 ® - Plan: MT6-06-MT"6-Bl-wp02_Drill South Plan: MT6-O6-MT6-06-Bl-wp02 Drill South Plan: MT6-07 - MT6-07 - Al -wp02 1,025.00 40.00 1,025.00 12.02 1,025.00 1.430 Centre Distance Pass -Major Risk Plan: MT6-07-MT6-07-A1-wp02 1,125.64 40.51 1,125.64 11.45 1,125.00 1.394 Clearance Factor Pass -Major Risk Plan: MT6-08 - MT6-08 - MT6-08-wp04 Lower Let Plan: MT6-08 - MT6-08 - MT6-08-wp04 Lower Let Plan: MT6-08-MT6-08PB1-MT6-08PB1-wp04 ® - Plan :MT6-O8-MT6-08PB1-MT6-08PB1-wp04 ® S - Plan: MT6-08 - MT8-08_Upper Let - MT6-08-wp04 ® - Plan: MT6-08 - MT8-08_Upper Let - MT6-08-wp04 ® - Plan: MT6-09-MT6-09-A2-wp02 1.025.00 79.95 1,025.00 51.97 1,025.00 2.856 Centre Distance Pass - Major Risk 12 April, 2018 - 15:25 Page 2 of 5 COMPASS ConocoPhillips Anticollision Report for Plan: MT6-05 - MT6-05-wp04_Lower Lat Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Plan: GMT1 Lookout Pad - Plan: MT6-05 - MTS -05 - MT6-06-wp04_Lower Let Scan Range: 0.00 to 16,920.06 usft. Measured Depth. Scan Radius is 1,888.41 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design Plan. MT6-09 - MT6-09 - A2-wp02 WNS (Various) Lookout 1 - Lookout 1 - Lookout 1 Survey POD/ program Measured Minimum @Measuretl Depth Distance Depth (usft) (usft) (usft) 1,227.87 81.07 1,227.87 12, 820.99 1,325.50 12, 820.99 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Ellipse @Measuretl Clearance Summary Based on (usft) Separation Depth Factor Minimum Separation Wanting (usft) usft 300.00 2,054.00 MT6-05-wp04_Lower Let 50.91 1,225.00 2.688 Clearance Factor Pass - Major Risk 1,105.50 7,975.00 6.025 Clearance Factor Pass - Major Risk From To Survey/Plan Survey Tool (usft) (usft) 36.00 300.00 MT6-05-wp04 Lower Let BLIND 300.00 2,054.00 MT6-05-wp04_Lower Let MWD 300.00 2,054.00 MT6-05-wp04_Lower Let MWD+IFR-AK-CAZ-SC 2,054.00 8,982.00 MT&05-wp04_Lower Let MWD 2,054.00 8,982.00 MT6-05-wp04 Lower Let MWD+IFR-AK-CAZ-SC 8,982.00 11,000.00 MT6-0&wpO4_Lower Let MWD 8,982.00 11,000.00 MT6-05-wp04_Lower Let MWD+IFR-AK-CAZ-SC 11,000.00 16,919.00 MT6-05-wp04_Lower Let MWD 11,000.00 16,919.53 MT6-05-wPO4_Lower Let MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -0n 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. 12 April, 2018 - 15:25 Page 3 of 5 COMPASS ConocoPhillips MT6-05 WP04 LADDER VIEW The reference well is along the Y-axis. Error Ellipses are the sum of the reference and offset well errors. BA U&S GEca ,, a o 0 s o 0 0 16 o c c O u) C O d 0) !A d c d U -Equivalent Magnetic Dietan d U 0 1000 2000 3000 Partial Measured Depth (5D0 usft/in) SURVEY PROGRAM CASING DETAILS Date: 2017-03-16T00:00:00 Validated: Yes Version: TVD MD Name Size 2032.72 2054.00 13-3/8" x 16" 13-3/8 Depth From Depth To Survey/Plan Tool 7099.00 8981.903-5/8" x 12-1/4" 9-5/8 36.00 300.00 MT6-05-wp04_Lower Lat (MT6-05) BLIND 7958.65 11000.00 7" x 8-3/4" 7 300.00 2054.00 MT6-05-wp04_Lower Lat (MT6-05) MWD 7970.00 16919.53 4-1/2" x 6" 4-1/2 300.00 2054.00 MT6-05-wp04_Lower Lat (MT6-05) MWD+IFR-AK-CAZ-SC 2054.00 8982.00 W6-05-wp04_Lower Let (MT6-05) MWD 2054.00 8982.00 MT6-05-wp04_Lower Lat (MT6-05) MWD+IFR-AK-CAZ-SC 8982.0011000.00 MT6-05-wp04_Lower Lat (MT6-05) MWD 8982.00 11 000.00 MT6-05-wp04_Lower Lat (MT6-05) MWD+IFR-AK-CAZ-SC 11000.0016919.00 MT6-05-wp04_Lower Lat (MT6-05) MWD 11000.0016919.53 MT6-05-wp04_Lower Lat (MT6-05) MWD+IFR-AK-CAZ-SC o a 0 rn 0 0 R F e m is q 0 r 16ti 0 0 F o E c io c c C i C O l0 a d rn d i= "Equivalent Magnetic Distan 0- .Boo0 v c d U 0 900 1800 2700 Partial Measured Depth (450 usft/in) ConocoPhiiiips Protect Western North Slope Site: Plan: GMT4 lookout Pad rAmw.miu Nem, M.eww NOM. re.n• u.en.n=F„a WELLBORE DETAIL$: MT6-05 REFERENCE INFOWMTION Parent Wellbore: No wellbore tlaW is avails C°era'irem RemreMe: well Fkn: 806a5. ima Nom Well: Plan: MT6-06 sn.�ern nuxe.� Ti. on MD: 36.00 venta(NDI Relemme:WELL@ 7009wa for” Wel Elea M) Wellbore: MT6-06 oo amu. w.7r Smum lvs)Re vwn: smi-(O.WN. o.WE) Plan: MT6-06-wpO4_Lowei tat (Plan: MTB-06/MT6-06) �Mpi nreexur Vmirerr. C01MIme(pgtr�tl wet Devi 5962000 y�K C&wlm M� IUGHES a GEcompany 1447200 1448100 1449000 1449900 1450800 1451700 1452600 Easting (450 1453500 1454400 usft/in) 1455300 1456200 1457100 1458000 1458900 1459800 1460700 1461600 5962000 5T6A1. 5962000 . 641 ^ �- 10 e0 e�U �0a0 3NUS6 �vC� RS U J4UayeaU b 1 pv^ 5i 5960000 5960000 l�ST9;t6A0. 0 5958000 5958000 5956000 yo5 'v JPU` 5956000 6,p5R� p5 USBTS65935 5954000 P\" O 59540005 3 p p S01 6G ON5S6 pe11.4A t9 y0 S6USR1• r 952000v\� e 59520000 T ePoq A' I�T�pjpO O y Pi 50 p,,T6AiMTtr03V01 O 1. L79 '�f V4�`m an` �y x,5950000 5950000 �Fc 4i\ 5948000 JOOn 5948000 SbUs 9 e°8 Jpp U�Y., RUS ,�3 HSTF 11°1 5946000 5946000 �O CA`C`tb� 5944000 Mtb po^a 5940000 �qR �Oa 5942000 5942000 1447200 1448100 1449000 1449900 1450800 1451700 1452600 1453500 1454400 1455300 1456200 1457100 1458000 1458900 1459BOO 1460700 1461600 Easting (450 usft/in) Bettis, Patricia K (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophiIli ps.com> Sent: Thursday, April 12, 2018 4:49 PM To: Bettis, Patricia K (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL]GMTU MT6-05 (PTD 218-045): Permit to Drill Application Attachments: MT6-05wp04 AC Reports.pdf Good afternoon Patricia and Guy, Please see the attached AC report, the wells that failed the AC are planned well and will be re -designed after this well drilled. Weifeng Office: ( 907)-263-4324 Cell Phone: (907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, April 12, 2018 10:34 AM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]GMTU MT6-05 (PTD 218-045): Permit to Drill Application Good morning Weifeng, The collision avoidance analysis was missing from the application. Please submit. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7`" Ave., Ste 100 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.aov. Bettis, Patricia K (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Wednesday, April 11, 2018 3:41 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]GMTU MT6-05 (PTD 218-045): Permit to Drill Application Hey Patricia, Sorry for the inconvenience, must be excel format messed it up. Please see the table below for the acreages for all the 3 leases. Lease No/propeAy Desi{. DNR Approval No Anes iln PropyW AA081798 AA081818 AA092346 Weifeng Office: (907 )-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 11, 2018 3:33 PM To: Dai, Weifeng<Weifeng.Dai@conocophill ips.com> Subject: [EXTERNAL]GMTU MT6-05 (PTD 218-045): Permit to Drill Application Good afternoon Weifeng, Could you please provide the acreage for all three leases which the MT6-05 wellbore crosses? The numbers were all run together on the application form. Thanks so much, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 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.bettisPalaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: / PTD: Ql'� Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: 6I`&J6r 190F61 /ck7t, /',t'POOL: G417 lir '�n•' nEC� .J 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 (If last two digits No. API No. 50- Production should continue to be reported Fas 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 producelinject is contingent upon issuance of a consonSpacing Exception order approving a spacing exception. (Company Name) Otor assumes the liability of any protest to the spacing exception thay occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sam les are fust cau t and 10' sam le intervals throu h tar et zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well until after (Company Name) has designed and Well implemented a water well testing program to. provide baseline data on water quality and quantity. (Corn nyName) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Commanv Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / ✓ Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC wiWdays after completion, suspension or abandonment of thio well Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, ALPINE UN 0 - 28210 Well Name: GREATER MT UNIT MT6-05 _ Program DEV Well bore seg ❑ PTD#:2180450 Company CONOCOPHILLIPS ALASKA. INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to A831,05,030(j. 1.A),(j.2.A-D) _ ___ _ _ NA.. oT3 1 Permit fee attached . . . . . . . . . . . . . . . ... . .. . .. . ........... - - - _ - -NA - _ ..... 2 Lease number appropriate ............................... . . . . . . . .. .Yes .. _ _ AA0081798,. Surf; AA0081818,_ Portion of Well; AA0092346, Top Prod Intery & TO. ... ............ 3 Unique well name and number------------------------------------- Yes... __..GMTV MT6-05---------..........._..---..__.._........ -------------..... 4 Well located in a defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _______ _ ____ _ No _ _ _ _ _ _ _ Application for Pool Rules Lookout Oil Pool received 2/28/28._ As of 4/12/18, application under review._ 5 Well located proper distance from drilling unit boundary . . . ........... . . . . . . . Yes 6 Well located proper distance from other wells............ Yes 7 Sufficient acreage available in drilling unit ... . . . . . . . . . . . . . .............. Yes _ 8 If deviated, is wellbore plat included . . . . ................. . . . . . . . . . Yes 9 Operator only affected party _ .................... . . . . . . . Yes Wellbore will be. more than 500' from an external property line where ownership or landownership changes.. _ 10 Operator has appropriate bond in force _ _ _ _ _ _ .. Yes Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ ... _ _ _ _ _ _ Yes _ _ _ _ _ _ _____ 12 Permit can be issued without administrative. approval Yes PKB 4/12/2018 _ _ _ _ _ _ _ _ 13 Can permit be approved before 15 -day wait_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ...... Yes 14 .Well located within area and. strata authorized by Injection Order# (put 10# in. comments) (For. NA_ 15 All wells Within 114 mile area of review identified (For service well only) .............. . NA_ _ _ _ _ _ _ _ _ _ ......... 16 Pre -produced injector: duration of pre produg8on less than 3 months. (For service well only) _ NA .......... 18 Conductor string. provided ....................... . . . . . . . . . . . . . . . . .. Yes _ _ _ _ _ _ _ 20" conductor sot at 115 ft. ------------------------------------ --------------- Engineering 19 Surface casing_ protects all.known USDWs _ _ _ _ _ _ _ _ ....NA .... _ _ No aquifers _ permafrost area . . . ............ 20 CMT vol adequate to circulate. on conductor & surf. rag _ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ Yes _ _ _ _ _ . 13 3/8" serfage casing will be fully cemented. 21 CMT voladequate to tie-in long string to surf rsg_ _ .......... ..... . . . . . No_ _ _ _ ... _ 9 5/8" int, 1 dasing will, be cemented. 500 ft from shoe 22 CMT. will rover all known_ productive horizons____________ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Yes ... _ Lateral willhave slotted liner 23 Casing designs adequate for C, T, B 8. permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ Yes _ _ _ _ _ _ _ BTG supplied on previous well of similar design.. MT6.03_ 24 Adequate. tankage or reserve pit _ _ _ _ . . . . . . . . ...... . .. Yes _ _ Rig has steel pits. All waste will bek transported to approved disposal well. 25 If a re -drill, has a 10-403 for abandonment been approved _ _ _ _ ___ _ _ _ _ _ _ _ NA _ ... grassroots well 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ Yes .... _ 2nd well on pad,... no issues yet but need further planning for new wells. _ 27 If diverter required, does it meet regulations. _ _ _ _ _ _ . Yes Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ _ _ ....... _ _ _ Yes _ _ _ Max formation = 3810 psi (9.2 ppg.EMW) 8.8 ppg w/MPD_will be used for drilling lateral._ GLS 4/19/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _______ _ _ _ Yes _ _ _ _ Doyon 19 ROPE on file with AOGCC 30 BQPE_press rating appropriate; test to (put psig in comments) .......... . . . . . . . . . Yes ..... 31 Choke. manifold complies w/API. RP -53 (May 84).. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _______ _ _ Yes _ _ _ No stimulation is planned for well at this time. 33 Is presence of 1-12S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___________ _ _ _ Yes _ _ _ H2S not expected but rig has -sensors and alarms.. 34 .Mechanical condition of wells within AOR verified (For service well only) . . ....... . . . . . NA _ _ _ _ -------- ......_35 35 Permit ran be issued w/o hydrogen sulfide measures .......... . . . . . . Yes .... H2S measures required, Geology 36 Data presented on potential overpressure zones _ _ .. Yes .... _ _ Expected reservoir pressure is 10.34 ppg. EMW r will be drilled using 9.0 to 11.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ NA_ _ _ _ Production. interval will be drilled using 8.8 ppg mud. 7" rag shoe to be satin top of Alpine C reservoir. PKB 4/12/2018 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ NA 39 Contact name/phone for weekly progress reports [exploratory only] _ _ _ _ _ _______ _ _ _ _ NA _ _ _ _ . Onshoredevelopment well to, be drilled, Geologic Engineering Public Will also drill lateral above T' casing shoe (MT6-05L1) Commissioner: Date: Commissioner: Date CommisQ' r oT3 l } COate O Zu 1,e,