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215-006
� 215006 27358 TRANSMITTAL 0. PROACTivE DIAgNOSTic SERVICES, INC. DATA LOGGED M.K.BENDER JUL a 6 20V6 To: AOGCC , '' Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Diane F. Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCOW DEC 0 1ZO16 1) Coil Flag 07-Jun-16 2L-316 Color Log /CD 50-103-20704-00 2) Signed : )'294t4AJ , './-E''ti'� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D3Achives\MasterTemplateFiles\Templates\Dish'ibution\TransmittalSheets\ConocoPhillips_Transmit.docx STATE OF ALASKA • ' AOKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate r Pull Tubing Operations Shutdown Performed: Suspend IT Perforate F Other Stimulate I— Alter Casing IT Change Approved Program r-- Plug Plug for Redrill IT Perforate New Pool IT Repair Well Re-enter Susp Well I- I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory IT 215-006-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20704-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380052,ADL 380051 KRU 2L-316 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 14990 feet Plugs(measured) None true vertical 5522 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 11968 true vertical 0 feet (true vertical) 5328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 155 155 SURFACE 2479 10 3/4 2518 2407 RECEIVED INTERMEDIATE- 12151 7 5/8 12188 5367 G? g. I 4.5"LINER 2962 41/2 14975 5521 luI\ 2 3 2016 . O®s.A CC Perforation depth: Measured depth: 12776-12779, 13142-13144, 13506-13508, 13868-13870, 14192-14194, 14450-14925 True Vertical Depth: 5445-5445, 5475-5475', 5504'-5505, 5517'-5517', 5514'-5514', 5514'-5520' Tubing(size,grade,MD,and ND) 3.5, L-80, 12032 MD, 5339 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 11968 MD and 5328 TVD 12.Stimulation or cement squeeze summary: r DEC {�I Intervals treated(measured): none SCANNED UC 0 6 201U Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 357 459 16 741 260 Subsequent to operation 802 747 2 771 240 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory IT F DevelopmentService ra Stratigraphic IT Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL Printed and Electronic Fracture Stimulation Data[- GSTOR IT WINJ IT WAG IT GINJ E. SUSP IT SPLUG IT 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Robert Blakney a 265-6417 Email Robert.G.Blakneyc conocophillips.com Printed Name Robert Blakney Title Sr. Wells Engineer Signature QPhone:265-6417 Date /z 3 //6 v`rL 7l40(. Form 10-404 Revised 5/2015 Z�_ // RBDMS L,1./L,1./JUN L 3 2016 Submit Original Only • • 2L-316 DTTMSTAF JOBTYP SUMMARYOPS 6/7/16 SCALE RIH with PDS GR&CCL down to TD at 14,960' CTMD. Log up to INHIBITION 14,300' and paint flag. Log up to 13,000' and then POOH. Parrafin encountered from 1,382' down to 2,470' CTMD. Download data and correlate depth. Return in morning to perf. **Job in Progress** Swab V opened at 0945 hrs and closed at 1935 hrs 6/8/16 SCALE RIH with 30'of 2" HSD PowerJet Nova 2006 6 spf, 60 degree INHIBITION phasing perf guns and perforate at the corrected depth of 14,450' to 14,480' . **ASF Verified**. Well freeze protected. ***Job Complete*** KUPOD • 2L-316 ConocoPhillips -'ittr" Well Attribu Max Angle&MD TD s Alaska he,. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CorrocoPbiigps 501032070400 TARN PARTICIPATING AREA PROD 91.07 14,023.98 14,990.0 ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-316,6/22/201675357 AM SSSV:NIPPLE 30 11/23/2015 Last WO: 39.81 5/5/2015 Vertical schematic{actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;35.0_,5.l.-amm--E-y Last Tag Rev Reason:PERF,H2S pproven 6/9/2016 Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "" '"'CONDUCTOR 16 13.938 40.0 155.0 155.0 164.98 ' s 11 I_ Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 38.8 2,518.0 2,407.1 45.50 L-80 TSH 563 XO Reducing;79.7 4.F Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE-7.625" 7 5/8. 6.875 37.0 12,187.8 5,366.7 29.70 L-80 Hydril563 ..."-^..CONDUCTOR,40.-155.0 1AB,„II x 8 52"@11747 - - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread NIPPLE;529.5 4.5"LINER 4 1/2 3.958 12,013.0 14,975.1 5,521.1 12.60 L-80 IBT-m Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;38 8-2,518.0 - 12,013.0 5,336.0 79.71 HANGER BAKER HRD-E ZXP FLEX LOCK LINER HANGER 4.250 in 12,032.6 5,339.5 79.74 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4240 GAS LIFT;2,717.4 12,035.0 5,339.9 79.75 HANGER BAKER FLEX LOCK LINER HANGER 4.800 12,044.4 5,341.6 79.77 XO Reducing 5.5"Hyd 563 box x 4.5"Hyd 563 pin Crossover 4.800 GAS LIFT;5,181.0 - Coupling 12,592.5 5,426.5 82.14 SWELL BAKER SWELL PACKER"G" 3.958 GAS LIFT 7,894.2 PACKER 12,776.4 5,447.9 84.27 FRAC PORT BAKER FRAC SLEEVE#6(2.125"BALL,DRIFT ID 2.700 ,: 2.093")-Milled to 2.70 GAS LIFT;9,882.0 12,954.4 5,464.1 85.71 SWELL BAKER SWELL PACKER"F" 3.958 PACKER 13,141.6 5,474.9 85.87 FRAC PORT FRAC SLEEVE#5(2.0"BALL,DRIFT ID 1.8751- 2.700 Milled to 2.70 13,321.7 5,491.0 84.81 SWELL BAKER SWELL PACKER"E" 3.958 GAS LIFT;11,858.8 PACKER 13,506.0 5,504.5 86.65 FRAC PORT BAKER FRAC SLEEVE#4(1.875"BALL,DRIFT ID 2.700 ;: 1.750")-Milled to 2.70 SLEEVE;11,917.8 13,684.7 5,512.3 88.40 SWELL BAKER SWELL PACKER"D" 3.958 GAUGE;11,941.8 PACKER 13,867.9 5,516.7 88.92 FRAC PORT BAKER FRAC SLEEVE#3(1.750 BALL,DRIFT ID 2.700 PACKER;11,987.8 - 1.625")-Milled t0 2.70 XO Threads;11,975.7 7. 411E 7 14,047.8 5,516.6 91.02 SWELL BAKER SWELL PACKER"C" 3.958 NIPPLE;11,995.8 .,,y5, ; PACKER 14,192.2 5,514.4 90.66 FRAC PORT FRAC SLEEVE#2(1.625"BALL,DRIFT ID 1.5")- 2.700 LOCATOR;12,013.1 SUB;12,014.1 I. Milled to 2.70 II Il I� ', 14,372.3 5,513.1 89.83 SWELL BAKER SWELL PACKER"B" 3.958 MULE SHOE;12,031.0 II . PACKER F`_� 14,557.9 5,514.6 89.25 FRAC PORT BAKER FRAC SLEEVE#1(1.5"BALL,DRIFT ID 2.700 01 ', 1 430")-Milled to 2.70 14,740.5 5,517.3 89.33 SWELL BAKER SWELL PACKER"A" 3.958 .I i i;: PACKER INTERMEDIATE-7.625"x8.57 Tubing Strings e11747;37.0-12,187.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft../Set Depth ITVD)(...Wt Ob/ft) Grade Top Connection TUBING-4 5"x 3 5" 3 1/2 2.992 35.0 12,032.3 5,339.5 9.30 L-80 EUE8rd lliliir @ 79 68 PERFP;12,776.4 , Completion Details FRAC;1212,7707778.4�� Eil I Nominal ID Top(ftKB) Top(ND)(MB) Top Incl(°I Item Des Com (in) 35.0 35.0 0.00 HANGER CAMERON TUBING HANGER 3.900 T ' 79.7 79.7 0.36 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE 8rd pin 2992 529.5 529.0 4.55 NIPPLE CAMCO DS NIPPLE 2.875 FRAC 13,141 s 11,917.6 5,318.8 79.56 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813"DS PROFILE 2.810 PERFP;13,141.813,143.9 (CLOSED) 11,941.8 5,323.2 79.58 GAUGE SLB GAUGE CARRIER 2.913 liillir 11,967.6 5,327.9 79.63 PACKER BAKER PREMIER PACKER 2.880 ( 11,995.6 5,332.9 79.68 NIPPLE CAMCO D NIPPLE(RHC PULLED 5/23)SET CAT SV 2.750 FRAC;13,508.2 8/2/2015 PERFP;13,506.0-73,5082 t , 12,013.1 5,336.0 79.71 LOCATOR BAKER SPECIAL SHEAR FLUTED NO-GO LOCATOR 3.000 12,014.1 5,336.2 79.71 SUB BAKER SPECIAL SHEAR LOCATOR SUB 3.000 12.031.0 5,339.2 79 74 MULE SHOE BAKER SPECIAL SHEAR TYPE WLEG ) 3.000 Perforations&Slots FRAC;13,887.0 %. I Dens PERFP;13,067.9-13,870.2 Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 12,776.4 12,778.7 5,447.9 5,448.1 5/2/2015 PERFP Frac Port 13,141.6 13,144.0 5,474.9 5,475.1 5/2/2015 PERFP Frac Port 13,506.0 13,508.3 5,504.5 5,504.7 5/2/2015 PERFP Frac Port FRA;14,192.2 13,867.9 13,870.2 5,516.7 5,516.8 5/2/2015 PERFP Frac Port PERFP;14,192.2-14,194.5-� ;: 14,192.2 14,194.5 5,514.4 5,514.4 5/2/2015 PERFP Frac Port 14,450.0 14,480.0 5,513.7 5,513.9 6/8/2016 6.0 IPERF 6 spf,60 degree phasing perf guns and perforate liliI at the corrected depth of 14,450' to 14,480' IPERF;14,450.0-14,400.0 14,557.9 14,5602 5,514.6 5,514.7 5/2/2015 PERFP Frac Port PERFP;14,557.814,560.2 14,915.7 14,925.6 5,519.6 5,519.9 5/2/2015 PERFP Perf Pup Stimulations&Treatments liiiir Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (kKB) (ftKB) Type Date Com FRAC;14,915.71 I 12,776.4 12,778.7 5,447.9 5,448.1 FRAC 7/13/2015 551588 16/20 FRAC SAND 1-6 PPA PERFP;14,815.7-14,925.6 ''+ ' 13,141.6 13,143.0 5,474.9 5,475.0 FRAC 7/4/2015 114044#16/20 FRAC SAND 1-6 PPA 4.5"LINER;12,013.014,975.1 1 t Illibik KUP 40OD • 2L-316 t onocoPhillips • Alaska.Inc. Conoc*Phillips ••••• HORIZONTAL-2L-316,622/2016 7:53:57 AM Vertical Usherette(actual) HANGER,35.0—•.::1—dtlAS--t>i- Stimulations&—reatments • Min Top Max 850 Depth Depth Top(ND) Btm(ND) . (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 13,506.0 13,508.0 5,504.5 5,504.6 FRAC 7/4/2015 117254#16/20 FRAC SAND 1-6PPA xo Reducing;79.7 IF 13,867.0 13,869.0 5,516.7 5,516.8 FRAC 7/4/2015 1379440 16/20 FRAC SAND 1-6PPA IF 14,192.2 14,194.2 5,514.4 5,514.4 FRAC 7/4/2015 1196330 OF 16/20 FRAC SAND 1-6 PPA . M CONDUCTOR,40.0-155.0 • 14,915.7 14,917.0 5,519.6 5,519.7 FRAC 6/28/2015 99973#of 16/20 frac sand 1-6 ppm WI NIPPLE;529.5 — Mandrel Inserts St ati °^ Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (ftKB) Make Model OD lin) Sery Type Type (in) (psi) Run Date Com SURFACE;38.6-2,518.0` d 2,717.4 2,571.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,628.0 8/6/2015 GAS LIFT;2,717.4 2 5,161.0 3,602.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/6/2015 iak 3 7,894.2 4,357.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/6/2015 4 9,882.0 4,905.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/4/2015 GAS LIFT.5,1610 II- 5 11,858.6 5,308.1 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 8/4/2015 DCK- 2 Notes:General&Safety GAS LIFT,7,894.2 End Dale Annotation NOTE GAS LIFT;9,882.0 :, jr r r 4; GAS LIFT;11,858.6 - SLEEVE;11,917.6 . 111 GAUGE;11,941.8 _ PACKER;11,887.6 XO Threads;11,975.7 NIPPLE;11,995.6 II'- LOCATOR;12,013.1 SUB;12,014.1 _ MULE SHOE,12,031.0 I III it INTERMEDIATE-7.625"x 8.52" ©11747;37.0-12,187.8 P ERFP;12,776.4-12,778.7 FRAC;12,776.4L_,;$ IS FRAC;13,141.6 P ERFP;13,141.8-13,143.9, I FRAC;13,506.0 PERFP;13,506.0-13,508.2 l I FRAC;13,887.0 PERFP;13,867.9-13,870.2 } FRAC;14,192.2 P ERFP;14,192.2-14,194.5I I IPERF;14,450.0-14.480.0 PERFP;14,557.9-14,567.2 FRAC;14,915.7 $$jjam�j PERFP;14,915.7-14,925.6 . -$itj.` ' 4.5-LINER,12,013.0-14,975.1- .1 t • • lD O 07 Lu t9 w - L7®o Q U`NZ -�m in Q N c a) E E cc o C7., U 1025 SO r O •rNV N CO-� O N # O O CO CO LO CO O N O • C ------ u) COcry V V CO CO N- M CO N 4-, _ E C -� CO r- N O O O O O O �, __ Ems .: E 0 2 g _ �X N C � � _v � (r O HC:13- EC, Iy d C O O N .,,p M y �t co v Pi (� = a) '- O co .- o 0 0 0 0 0 U xmC -o > CI Lin -c CV � coiQs Z c C O i j) . . ,-U II a) a) 03 6L N0 _c v Q 0 c o 0 0 N- a) 1,I . k.../ U) Z O O N c- ', ) CO V irs CO Q O O O r co N 7 O— Q a) ,Z (O 6) n O O) a) to -c N L a -3 a) ,fCD 2 _c 3 0 ca a? co O- C N U i 10 CO >+ 0 U) (0 0 0 M - (- O /� - a:50 C Cl) - O O o0'�'N O O m x" 0 0 75w E CLE O'O u) m 0 M co O Q (() CO 2 w N 2 _ N 0 N N O C O J cno,N Q I. 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CL 0 < C/) Q (n M 0_N N L u '0 0_C.D < • 0 0 O O O O O O O 0 0) 0 M 7 N N 2 co co co co co co O 0 co 0 co co co co O O co co co co a) O O 0 0 0 L 0) a) 0 0) OS 0) 0)(0 5 2 ✓ (O (() O O N N M O Q- M (O M O V C Q I� O O Lo O M M M O O (O (O M o O O O) N I- U) O OS E O O L O v) C 4- o O O ` > (0 C 0 U O ) d E > M L O) O C L• 't) = o 0 @ C O p N E �+N N 6 V X 00 R7 1.0 >,O) O0 0 C L M N 6'0 N x U C• O N r O 4) a) N N'N C '�,C 0 C U7 a) E X E L co O n 4 OL N'p OSL (0< O OLN O 0) •_ 0 (!1,UJ m1- (n -L 2,am d� 3C o — oLL O o - 4 (6 U 7 C 0 C O O 0) C d O N U Q OS O 1.13 � YU .m v)N j • O O U 6 a n U j V) C Eo T X "O (6 co co o N a E 00 U y C L N U C O O a O O N E 0) > _o 0)17.3 o E > - -o C O O -C N14-4 O C t (0 O N O C 0 O) zc RECEWED ConocoPhillips OCT 2 3 2013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 28, 2015 SCANNED MAY 1 8 201E al 5- Commissioner Cathy Foerster Alaska Oil& Gas Commission a L- 3/6 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043,if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor MIIIIIIIIft 0 S ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 (e)2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 STATE OF ALASKA I AL.A OIL AND GAS CONSERVATION COIVIOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate Pull Tubing r Operations Shutdown r Performed: Suspend j! Perforate r Other Stimulate {" Alter Casing r Change Approved Program Rug for Redrill Perforate New Pool Repair Well Re enter Susp Well Other. ('6 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 215-006-0 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20704-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380052,380051 KRU 2L-316 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 14990 feet Plugs(measured) None true vertical 5522 feet Junk(measured) None Effective Depth measured 14975' feet Packer(measured) 11968 true vertical 5521 feet (true vertical) 5328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 155 155' SURFACE 2479 10.75 2518 2407 INTERMEDIATE- 12151 7.625 12188 5367 4.5"LINER 2962 4.5 14975 5521' RECEIVED AUG 172015 Perforation depth: Measured depth: perf pups from 12776'-14926' True Vertical Depth: 5448'-5520' CANNE�I APR 0 121)16 /�®GCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 12032 MD,5339 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 11968 MD and 5328 TVD NIPPLE-529'MD and 529'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12776'-14926' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I Exploratory r Development 17 Service Stratigraphic r Copies of Logs and Surveys Run �U" 16.Well Status after work: Oil ( Gas ' WDSPL fl Printed and Electronic Fracture Stimulation Data Pi GSTOR r WINJ r WAG r GINJ r SUSP J SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-293 Contact Baskoro Tejo t 263-4724 Email Baskoro.Tejo(a conocophillips.com Printed Name Baskoro Tejo Title Completion Engineer Signature c to Phone:263-4724 Date � I y / i VLA // VEL 3 At/1 b C.DW i%sit' 7 //6 0- AUG 19 2015 o/��f /? 0- p4,4_ 2'S 2otie Form 10-404 Revised 5/2015 Submit Original Only is� `� tecew 2L-316 WELL WORK SUMMARY DATE SUMMARY S • 5/22/2015 GAUGED TREE, HANGER&4.5"TBG TO 3.905"TO 45' SLM. DISPLACED TBG WITH 120 BBL 776-DSL. SET BAITED P/T ON BALL 'N ROD @ 11955' RKB. PULLED SOV& SET DV @ 11858' RKB. MITT 4000 PSI, GOOD. IN PROGRESS. 5/23/2015 MIT IA 3500 PSI, GOOD. PULLED BALL 'N ROD & RHC PLUG BODY© 11995' RKB. READY FOR FRAC. 6/26/2015 Attempted to perform multi-stage fracture treatment. While prepping to pump, SLB computers in treatment van crashed. System was rebooted, however, incident occurred again approx an hour later. Suspect bad computer cables/connections, however, SLB unsure. Will swap out treatment van with back-up as well as frac pump that needed repairs. Job to resume in A.M. 6/27/2015 Attempted to perform frac.Crew left DH for KRU early(05:00)to get a jump on job; delayed to location by BP rig move. Once on location, encountered issues with PCM, forcing some crew to return to Deadhorse, load, and return with spare PCM. Finished rigging and P/T'd; will pump in A.M.. 6/28/2015 Attempted frac performing injectivity test, pad and 1-6#on first stage. Screened out as 6#sand hit the perfs. Attempted to inject/surge well to get fluid moving, unable. Pulled treesaver and rigged out frac equipment to allow for CTU to rig up. 6/29/2015 EGO DOWN TO 14192', PUMPED A TOTAL OF 2200 BBLS DOWN COIL X TBG. TRIED TO SHIFT SLEEVE WITH COIL AND SPECIAL SLEEVE SHIFTING NOZZLE. WAS NOT ABLE TO SHIFT SLEEVE, CAME OUT OF HOLE PICKED UP DJN, RBIH TO CLEAN OUT ONE MORE TIME GOING DOWN TO 14200' CTMD. CHASE OUT ANY REMAINING FRAC SAND. ****JOB IN PROGRESS**** 6/30/2015 ATTEMPTED TO SHIFT FRAC PORT AT 14,192' MD USING 1.625" SLEEVE SHIFTING NOZZLE. UNSUCCESSFUL IN ATTEMPT TO SHIFT USING MULTIPLE TECHNIQUES VARYING ENGAGEMENT SPEEDS AND PRESSURE SURGING. FREEZE PROTECTED WELL. ORDERED OUT A DIFFERENT DESIGN NOZZLE, 11 POUND BRINE, AND SEAWATER WITH SAFELUBE. JOB IN PROGRESS. 7/1/2015 WAITED FOR TOOLS TO BE BUILT AND BROUGHT OUT TO LOCATION, PUT ON SLEEVE SHIFTING NOZZLE, RIH TO SLEEVE CLEAN OUT WITH 15 BBLS GEL FOLLOWED BY 135 BRINE. TRIED MULTIPLE TIMES TO SHIFT SLEEVE. NO LUCK, ****JOB IN PROGRESS**** 7/1/2015 JETTED ON/IN FRAC PORT WITH 11# BRINE AT 1 BPM USING STINGER NOZZLE. RIH TO 12,200' CTMD PREPARING TO REVERSE OUT. C/O ON LOCATION. JOB IN PROGRESS. 7/2/2015 RIH WITH REVERSE OUT BALL SEAT NOZZLE, REVERSED OUT ANY REMAINING SAND THAT MAY HAVE BEEN ON THE FRAC SLEEVE. SURGED THE WELL MULTIPLE TIMES, DUMPING THE WHP TO THE TANKS, FINALLY BRINGING THE WHP TO 3300 PSI SLEEVE SHIFTED WHP FELL OFF TO 1700 PSI, COIL MOVED IN HOLE 1', CAME ONLINE DOWN THE BACKSIDE AT 3.3 BPM WHP 1524, IA 0, OA 339. PUMPED 55 BBLS DOWN BACKSIDE. WELL FREEZE PROTECTED. ****JOB IN PROGRESS**** 7/4/2015 PERFORM FRACTURE TREATMENT ON STAGES 3 THROUGH 6 PLACING 480,718#OF 16/20 CARBOLITE, SCREENED OUT AT END OF STAGE 6, 2.125 BALL IN WELLBORE WITH 50 BBLS 6PPA SLURRY, RIG DOWN FOR COIL. 7/6/2015 RIH DRY TAG AROUND 11,700', CLEAN OUT DOWN TO FRAC SLEEVE 12776', DO 4 BOTTOMS UP TILL WE GOT GOOD CLEAN RETURNS TO THE TANKS CHASING EACH BITE TO THE TUBING TAIL 12031', ONCE WE GOT CLEAN RETURNS TO SURFACE WE SHUT DOWN AND APPLIED PRESSURE TO SEE IF WE COULD SHEAR FRAC SLEEVE. AT 4200PS1 FRAC SLEEVE SHEARED AND PRESSURE FELL OFF, PUMPED 200BBLS DOWN BACK SIDE WHP 1650, IA 450, OA 459. WELL FREEZE PROTECTED. ****JOB IN PROGRESS**** 7/11/2015 PUMP FINAL FRACTURE STAGE#7, SCREENOUT ON 4PPA , PLACED 37125#OF 16.20 CARBOLITE, READY FOR COIL. 7/14/2015 PERFORMED POST FRAC FILL CLEANOUT FROM SURFACE TO HARD TAG @ 12738' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS © 1.9 BPM, MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, VERY HEAVY SAND CONCENTRATIONS OBSERVED. EST TOTAL SOLIDS VOLUME AT 100 BBLS, RETURN IN AM FOR MILLING OF FRAC SLEEVES, JOB IN PROGRESS. 7/15/2015 MILL OUT FIRST 3 FRAC SLEEVES AT 12776', 13141' & 13141' RKB, LOST ALL RETURNS AFTER MILLING 3RD FRAC SLEEVE, COIL TEMPERARILY DETAINED MULTIPLE TIMES WHILE POOH, RETURN IN AM TO DO A N2/FCO, JOB IN PROGRESS. 7/16/2015 PERFORM FILL CLEANOUT FROM 5000' CTMD TO HARD TAG AT 13827' CTMD (FRAC SLEEVE#4) PUMPING SLICK DIESEL WITH DIESEL GEL SWEEPS AT 1.9 BPM WHILE MAINTAINING 1:1 RETURNS OR LESS, VERY LIGHT SAND CONCENTRATIONS OBSERVED, RETURN IN AM TO MILL FINAL 3 FRAC SLEEVES, JOB IN PROGRESS. 7/17/2015 RIH TO MILL OUT 4TH AND 5TH FRAC SLEEVES AT 13867' & 14192' RKB, REAM ACROSS EACH 3 TIMES AND CHASE TO TBG TAIL, RBIH AND STACK OUT AT0' CTMD, MILL GOES INTO STALL, HEAVY OVERPUL OF 35K, CONTINUE TO PUH UNTIL UNA LE TO WORK ANY HIGHER AT 14111' CTMD, TRY JARRING, PUMPING DOWN THE BACKSIDE, SURGING THE COIL ALL WITH NO SUCCESS, CALL SLB TO SEND 2 ENGINEERS TO DRY WATCH OVERNIGHT, JOB IN PROGRESS. 7/18/2015 TRY TO GET PIPE FREE AT 14110' CTMD, UNABLE TO BREAK LOOSE IN TENSION (+70K) OR COMPRESSION (-15K), AFTER MULTIPLE ATTEMPTS TO SURGE CT AND WHP, WE ARE ABLE TO CIRCULATE AND SPIN MILL AT 1.5 BPM/2800 CTP, CALL FOR N2 TO CHANGE DOWNHOLE DYNAMICS, AFTER PUMPING N2 FOR 30 MINUTES WE ESTABLISHED RETURNS TO SURFACE, MOVED PIPE 146' (13965')WHILE RECIPRICATING PIPE UP/DOWN, HAVING N2 AND FLUIDS RELOADED, SLB ENGINEERS DRY WATCH FOR THE NIGHT, JOB IN PROGRESS 7/19/2015 CONTINUE TO TRY TO GET COIL UN-STUCK, BEGIN BY PUMPING N2 AT 1500 SCFM WHILE PUMPING 1 BPM OF DIESEL GEL, UNABLE TO GET ANY REAL MOVEMENT FROM PIPE, TRY PUMPING DOWN THE BACKSIDE AT 4 BPM, GET 50' OF COIL MOVEMENT UPHOLE FROM 13979'TO 13929', PUMP 5.2 BBLS OF MINERAL OIL AND LET SOAK FOR AN HOUR, PIPE BEGAN TO MOVE OOH, CONTINUE TO LET SOAK AND WORK PIPE UNTIL DRY WATCH CREW ARRIVES, TOTAL OF 460' OF PIPE PULLED OOH FROM 13979' CTMD TO 13519' CTMD, ORDERED 50 BBLS OF MINERAL OIL, RETURN IN AM TO GET PIPE FREE, JOB IN PROGRESS. 7/20/2015 BEGIN TRYING TO GET COIL FREE AT 13519' CTMD, PUMP 50 BBLS OF MINERAL OIL (LVT), LET SOAK FOR 1 HOUR, AS WE PULLED PAST 12700' TO 12300' CTMD ENCOUNTERED METAL EMBEDDED INTO THE COIL AS WELL AS MULTIPLE INDENTATIONS, BEGIN PULLING COIL OUT OF HOLE, DETAINED MULTIPLE TIMES AT 9200', 8650', 7800'AND 3489' CTMD, UNABLE TO GET FREE AT 3489' CTMD AND UNABLE TO GET CIRCULATION TO SURFACE, DROP 5/8" DISCONNECT BALL AND PULL COIL OUT OF HOLE, RETURN IN AM FOR BOP TEST AND TO FISH THE MOTOR AND MILL, JOB IN PROGRESS. 7/21/2015 PERFORM WEEKLY BOP TEST, CREW C/O, RIH TO FISH BHA, LATCH INTO FISH AT 3509' CTMD, GET 10 JARLICKS UP AND 1 DOWN, GS POPPED OUT OF THE FISHNECK, UNABLE TO GET LATCHED BACK IN,FOUND DAMAGE TO ONE OF THE DOGS ON THE GS, REPLACE GS AND STACK BACK FOR THE NIGHT, RETURN IN AM TO CONTINUE FISHING, JOB IN PROGRESS. 7/22/2015 RUN #1: RIH WITH GS, UNABLE TO GET LATCHED INTO THE FISHNECK DUE TO DAMAGED DOG ON THE GS AGAIN, RUN #2: RIH WITH VENTURI BASKET TO RECOVER WHAT IS SUSPECTED STATOR RUBBER FROM THE MOTOR, RUN #3: RIH WITH GS, PUMP 7 BBLS OF MINERAL OIL (LVT)AND PUMP PAST THE FISH, STACK-15K AND FISH COMES FREE, RECOVERED MOTOR AND MILL, BLOW DOWN REEL WITH N2 FOR REEL SWAP, JOB IN PROGRESS. 7/27/2015 RIG UP CTU, PUMP A 1 3/8" DRIFT BALL, P/T & FUNCTION TEST BOP'S, MAKE 2 MAGNETNENTURI RUNS TO 4000' CTMD, VENTURI CAME BACK EMPTY BOTH TIMES AND THE MAGNET WAS COMPLETELY FULL OF METAL CUTTINGS, EST TOTAL OF 1 CUP OF CUTTINGS RECOVERED, JOB IN PROGRESS. 7/28/2015 RIH WITH VENTURI AND MI MAGNETS, RECOVERED SOME FINE METAL SHAVINGS ON THE MAGNETS AND A FLOATING 5/8" BALL IN THE VENTURI. CUT 25' COIL, CHANGE PACK OFFS, DID CHAIN INSPECTION. ****JOB IN PROGRESS**** 7/29/2015 RIH WITH FCO BHA AND MI MAGNETS, CLEANED OUT DOWN TO 13,700'TAKING 100' BITES, DID WIPER TRIPS THROUGH OUT THE CLEAN OUT, LOST RETURNS WHILE CHASING OUT FILL, GOT HUNG UP FOR SEVERAL HOURS BEFORE FINALLY GETTING FREE. ****RESTART IN THE MORNING**** 7/30/2015 RIH WITH FCO BHA. START CLEAN OUT FROM SURFACE PUMPING 1.3 BPM AND 400SCFM N2, CLEAN OUT DOWN TO 13130'. DID WIPER TRIP UP TO 2000'. ****JOB IN PROGRESS**** 7/31/2015 RIH WITH MOTOR AND FRAC MILL, 2.70" OD, MILL FINAL FRAC SLEEVE @ 14557.9' RKB, MULTIPLE STALLS. PAINT ORANGE FLAG TO TIE IN FOR ADD PERF @ 14557.9' RKB, MADE 4 PASSES THROUGH FRAC SLEEVE, CHASE FINAL GEL SWEEP OUT OF HOLE PUMPING N2 AND SLICK DIESEL. ****JOB IN PROGRESS**** 8/1/2015 ATTEMPTED TO PERFORATE 14,450'-14,480'WITH SLB 2" 6 SPF NOVA GUNS. UNABLE TO REACH DESIRED DEPTH DUE TO POTENTIAL WEIGHT TRANSFER AND DIFFERENTIAL STICKING ISSUES. MAXIMUM DEPTH REACHED = 14,080' CTMD. JOB TURNED OVER TO SLICKLINE TO INSTALL GLD. *JOB IN PROGRESS* 8/2/2015 DRIFT DOWN TO 12,678' RKB (STALLED DUE TO DEVIATION) & MEASURE BHP © SAME (2366 PSI); SET 2.75" CAT SV @ 11996' RKB & PULLED DV© 11859' RKB (LATCH SEVERELY ERODED). READY FOR CIRC OUT. IN PROGRESS. 8/3/2015 circ out well 2L-316, rigged up to 7"tree cap,pump'd down tubing,up IA, retruns to well 315 flow line pump'd 290 bbls CRW S/S i pump'd140 bbls Diesel U tube job complete 8/4/2015 SET 5/16" OV @ 11859' RKB. PULLED DV FROM 9882' SLM. ATTEMPTED SET DV @ 9882' RKB. RAN CHECK SET TO 9882' RKB, UNABLE TO SIT DOWN. IN PROGRESS. 8/5/2015 FOUND DV @ 9882' RKB PARTIALLY IN POCKET; TAPPED INTO POCKET. DD TEST PASSED. PULLED DV FROM 7894' RKB. IN PROGRESS. 8/6/2015 SET DV @ 7894' RKB. PULLED DV FROM 5161' RKB, REPLACED IN KIND. PULLED DV FROM 2717' RKB, SET GLV @ SAME. ATTEMPTED TEST TBG. IN PROGRESS. 8/7/2015 MIT TBG 3000 PSI, PASSED. PULLED SV @ 11995' RKB. COMPLETE. KUP PROD 0 2L-316 Conoco jllj Well Attributes Max Angle&MD TD xaska I Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) [onocj4trarr, 501032070400 TARN PARTICIPATING AREA PROD 91.07 14,023.98 14,990.0 ew ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-316,7/2220157:30:17 PM SSSV:NIPPLE Last WO: 39.81 5/5/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;35.0 -..r y Last Tag: Rev Reason:FRACTURING lehallf 7/22/2015 ( Casing Strings `�' $ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread -- --- ^--CONDUCTOR 16 13.938 40.0 155.0 155.0 164.98 ^- - - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 38.8 2,518.0 2,407.1 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread XO Reducing.79.7 Mr INTERMEDIATE-7.625" 75/8 6.875 37.0 12,187.8 5,366.7 29.70 L-80 Hydril563 ,x852"x@11747 MIIN .A.x\/CONDUCTOR;40.0-155.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread 4.5 LINER 41/2 3,958 12,013.0 14,975.1 5,521.1 12.60 L-80 IBT-m NIPPLE;529.5 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl("I Item Des Com (in) 12,013.0 5,336.0 79.71 HANGER BAKER HRD-E ZXP FLEX LOCK LINER HANGER 4.250 SURFACE;38.8-2.518.0 - l - --- _ 12,032.6 5,339.5 79.74 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4 240 GAS LIFT;2,717.4lir 12,035.0 5,339.9 79.75 HANGER BAKER FLEX LOCK LINER HANGER 4.800 1 12,044.4 5,341.6 79.77 XO Reducing 5.5"Hyd 563 box x 4.5"Hyd 563 pin Crossover 4.800 GAS LIFT;5,161.0 Coupling 12,592.5 5,426.5 82.14 SWELL BAKER SWELL PACKER"G" 3.958 PACKER GAS LIFT;7,894.2 '3' 12,776.4 5,447.9 84.27 FRAC PORT BAKER FRAC SLEEVE#6(2.125"BALL DRIFT ID 3.950 2.093") 1; 12,954.4 5,464.1 85.71 SWELL BAKER SWELL PACKER"F" 3.958 GAS LIFT,9,882.0 PACKER 13,141.6 5,474.9 85.87 FRAC PORT FRAC SLEEVE#5(2.0"BALL,DRIFT ID 1.875") 3.940 13,321.7 5,491.0 84.81 SWELL BAKER SWELL PACKER"E" 3.958 ' ;' 13 ,506.0 5,504.5 86.65 FRACPACKER PORT BAKER FRAC SLEEVE#4(1.875"BALL,DRIFT ID 3.920 GAS LIFT;11,858.6 1.750") s. W 13,684.7 5,512.3 88.40 SWELL BAKER SWELL PACKER"D" 3.958 SLEEVE;11,917.6 r PACKER GAUGE;11.941.8 13,867.9 5,516.7 88.92 FRAC PORT BAKER FRAC SLEEVE#3(1.750 BALL,DRIFT ID 3.940 PACKER;11,967.6 @- 14,047.8 5,516.6 91.02 SWELL BAKER SWELL PACKER"C" 3.958 xo Threads;11,975 PACKER NIPPLE 11.995B _- ? 14,192.2 5,514.4 90.66 FRAC PORT FRAC SLEEVE#2(1.625"BALL,DRIFT ID 1.5") 3.930 14,372.3 5,513.1 89.83 SWELL BAKER SWELL PACKER"B" 3.958 LOCATOR;12,013.1 PACKER sue;12,014.1 14,557.9 5,514.6 89.25 FRAC PORT BAKER FRAC SLEEVE#1(1.5"BALL,DRIFT ID 3.930 MULE SHOE;12,031.0 - I' 1'430") 14,740.5 5,517.3 89.33 SWELL BAKER SWELL PACKER"A" 3.958 PACKER I I a ' Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(lb/ Grade Top Connection TUBING-45'x3.5" 31/2 2.992 35.0 12,032.31 5,339.5 9.30 L-80 IEUEBrd INTERMEDIATE-7.625"x8.52' @ 79.68 ©11747;37.0-12,187.8 Completion Details _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 35.0 35.0 0.00 HANGER CAMERON TUBING HANGER 3.900 PERFP;12,776.4-12,7787 FRAC;12,776.4'"1 1 1 I 79.7 79.7 0.36 XO Reducing Crossover 4 1/2"IBTM b e 3 1/2"EUE 8rd pin 2.992 529.5 529.0 4.55 NIPPLE CAMCO DS NIPPLE 2.875 11,917.6 5,318.8 79.56 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813"DS PROFILE 2.810 (CLOSED) 11,941.8 5,323.2 79.58 GAUGE SLB GAUGE CARRIER 2.913 FRAC;13,141.6 PERFP;13,141.6-13,143.9 t I I 11,967.6 5,327.9 79.63 PACKER BAKER PREMIER PACKER 2.880 11,995.6 5,332.9 79.68 NIPPLE CAMCO D NIPPLE(RHC PULLED 5/23) 2.750 12,013.1 5,336.0 79.71'LOCATOR BAKER SPECIAL SHEAR FLUTED NO-GO LOCATOR 3.000 12,014.1 5,336.2 79.71 SUB BAKER SPECIAL SHEAR LOCATOR SUB 3.000 FRAC;13,506.0 12,031.0 5,339.2 79 74 MULE SHOE BAKER SPECIAL SHEAR TYPE WLEG 3.000 PERFP;13,506.0-13,508.2-II 1 I I Perforations&Slots Shot Dens Top(ND) Btm IND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,776.4 12,778.7 5,447.9 5,448.1 5/2/2015 PERFP Frac Port FRAC;13,8670 p 13,141.6 13,144.0 5,474.9 5,475.1 5/2/2015 PERFP Frac Port PERFP;13,867.9-13,8702 l I 13,506.0 13,508.3 5,504.5 5,504.7 5/2/2015 PERFP Frac Port 13,867.9 13,870.2 5,516.7 5,516.8 5/2/2015 PERFP Frac Port 14,192.2 14,194.5 5,514.4 5,514.4 5/2/2015 PERFP Frac Port 14,557.9 14,560.2 5,514.6 5,514.7 5/2/2015 PERFP Frac Port FRAC;14,192.2 14,915.7 14,925.6 5,519.6 5,519.9 5/2/2015 PERFP Pert Pup PERFP;14,192.2-14,194.5-I I Stimulations&Treatments Min Top I Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 12,776.4 12,778.7 5,447.9 5,448.1 FRAC 7(13/2015 55158#16/20 FRAC SAND 1-6 PPA 13,141.6 13,143.0 5,474.9 5,475.0 FRAC 7/4/2015 114044#16/20 FRAC SAND 1-6 PPA PERFP;14.557.9-14,560.2 1 t 13,506.0 13,508.0 5,504.5 5,504.6 FRAC 7/4/2015 117254#16/20 FRAC SAND 1-6PPA 13,867.0 13,869.0 5,516.7 5,516.8 FRAC 7/4/2015 1379440 16/20 FRAC SAND 1-6PPA 14,192.2 14,1942 5,514.4 5,514.4 FRAC 7/4/2015 119633#OF 16/20 FRAC SAND 1-6 PPA 14,915.7 14,917.0 5,519.6 5,519.7 FRAC 6/28/2015 99973#of 16/20 frac sand 1-6 ppm 1111 C; 4 PERFP,14,915.7-1FRA14,925,,915.76 tii+"i 4.5"LINER;12,013.0-14.975.1 KUP PRODII 2L-316 ConocoPhillips Aas.1ka,(no. CUnnmNtiitio HORIZONTAL-2L-316.7/22/2015 7:30:17 PM Vertical schematic(actual) HANGER:35.0—sic_1c�m `11. I MIMandrel Inserts st .eti Top(TVD) Valve LatSRun N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Typech Port(in)lze TRO(psI) Run Date Cons 0.000 on 5/4/2015 X0 d ll Reducing.550 23 7,894.2 4,357.1 CAMCO KKBBmMGG _1 GGAASS LLIIFFTT DMY BK 0.000 0.0 5/4/2015 ✓� 0.000 0.0 5/4/2015 �./'CONDUCTOO R;40.0.155.0 � w_ 4 9,882.0 4,905.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 NE NIPPLE;529.5 5 11,858.6 5,308.1 CAMCO KBMG 1 GAS LIFT DMY BEK 0.000 0.0 5/23/2015 DCK-2 MB 1 / I Notes:General&Safety End Date Annotation SURFACE;38.8-2.5180 - NOTE: 1m GAS LIFT,2,717.4 WE GAS LIFT,5,161.0 MGAS LIFT;7,894.2 '3'c III GAS LIFT;9,882.0 IF GAS LIFT,11,8586t . SLEEVE,11,917.6 1 � � f II� GAUGE;11,941.8 PACKER;11,967.6 ""- XO Threads,11,975.7 NIPPLE;11,995.6 g 3 _-5 I Ma� LOCATOR;12,013.1 3 SUB;12,014.1 I MULE SHOE;12,037.0 II ,4 =1i INTERMEDIATE-7.625"x 8.52' ©11747,37.0-12,187.8 PERFP;72,776.4-12,77 RAC;1.7876.4-‘__11I FRAC;13,141.6 PERFP:13,141.6-13,143.9 ll 1 FRAC;13,506.0 PERFP;13,506.0-13,508.2 l l 1 FRAC;13.867.0. l PERFP;13,867.9-13,870.2 FRAC;14,192.2 PERFP;14,192.2-14,194.5® [1 PERFP;14,557.9-14.5602 8S I. FRAC;14,915.7 I °..,jOai' I PERFP;14,915.7-14,925.6 '} 4.5"LINER,12,013.0-14,975.1 • Client: ConocoPhillips Alaska Wharger Well: 2L-316 Basin/Field: Kuparuk River State: Alaska County/Parish: North Slope Borough Case: 631625158 Disclosure Type: Post-Job Well Completed: 7/11/2015 Date Prepared: 7/22/2015 4:22 PM Report ID: RPT-38146 Fluid Name'„ Additive i Additive Description Concentration Volume B882 Guar Polymer Slurry 0.7 Gal/1000 Gal 247.0 Gal D206 Antifoam Agent 0.03 Gal/1000 Gal 10.0 Gal F103 Surfactant 1 Gal/1000 Gal 353.0 Gal J475 Breaker _ 9.8 Lb/1000 Gal 3,494.0 Lb J511 Stabilizing Agent 1.5 Lb/1000 Gal 539.0 Lb YF100FIexD:WF100 357,171 Gal 1580 Gelling Agent 22.4 Lb/1000 Gal 7,993.0 Lb J604 Crosslinker 1.9 Gal/1000 Gal 673.0 Gal L065 Scale Inhibitor 1.8 Gal/1000 Gal 660.0 Gal M002 Additive 0.4 Lb/1000 Gal 141.0 Lb M275 Bactericide 0.8 Gal/1000 Gal 290.0 Gal S522-1620 Propping Agent varied concentrations 644,006.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number ���' Chemical Name Mass fraction Water(Including Mix Water Supplied by Client)* 1 81.55107 % 66402-68-4 Ceramic materials and wares,chemicals 17.74702 % 9000-30-0 Guar gum 0.24784 % 107-21-1 Ethylene Glycol 0.08131 % 7727-54-0 Diammonium peroxodisulphate 0.07852 % 1319-33-1 Boronatrocalcite 0.07763 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 1 0.03401 % 64742-47-8 Distillates(petroleum),hydrotreated light 0.03120 % 91053-39-3 Diatomaceous earth,calcined 0.02601 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01702 % 111-76-2 2-butoxyethanol 0.01521 % 67-63-0 Propan-2-ol 0.01521 % 50-70-4 Sorbitol 0.01485 % 34398-01-1 Alcohol,C11 linear,ethoxylated 0.01397 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00758 % 7647-14-5 Sodium chloride 0.00687 % 1330-43-4 Sodium tetraborate 0.00654 % 10377-60-3 Magnesium nitrate 0.00520 % 1310-73-2 Sodium hydroxide(impurity) 0.00407 % 10043-52-4 Calcium Chloride 0.00347 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one 0.00279 % -...._ ..................-- 7786-30-3 Magnesium chloride 0.00260 % 10043-35-3 Boric acid 0.00204 % 110-17-8 Fumaric acid 0.00204 % 7704-73-6 Monosodium fumarate 0.00204 % 112-42-5 1-undecanol 0.00122 % I 7631-86-9 Non-crystalline silica(impurity) 0.00105 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00084 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite 0.00081 % 14808-60-7 Quartz,Crystalline silica 0.00052 % 14464-46-1 Cristobalite 0.00052 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00052 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00037 % 63148-62-9 Dimethyl siloxanes and silicones 0.00036 % 108-32-7 4-methyl-1,3-dioxolan-2-one 0.00025 % 67762-90-7 Siloxanes and silicones,dimethyl,reaction products with silica 0.00023 % 9002-84-0 poly(tetrafluoroethylene) 0.00022 7447-40-7 Potassium chloride(impurity) 0.00011 % 125005-87-0 Diutan gum 0.00010 % 127-08-2 Acetic acid,potassium salt 0.00005 % 1338-41-6 Sorbitan stearate 0.00004% ©Schlumberger 2015.Used by ConocoPhillips Alaska by permission. Page:1/2 . • • Client: ConocoPhillips Alaska kibinberger Well: 2L-316 Basin/Field: Kuparuk River State: Alaska County/Parish: North Slope Borough Case: 631625158 Disclosure Type: Post-Job Well Completed: 7/11/2015 Date Prepared: 7/22/2015 4:22 PM Report ID: RPT-38146 6 i CAS NUM ber Chemical Name "' �� ih _ Mass Fract on 68153-30-0 Amine treated smectite clay 0.00003 % 68937-55-3 Siloxanes and Silicones,di-Me,3-hydroxypropyl Me,ethoxylated propoxylated 0.00002 % 68308-89-4 Fatty acids,C18-unsatd.,dimers,ethoxylated propoxylated 0.00002 36089-45-9 2-Propenoic acid,2-ethylhexyl ester,polymer with 2-hydroxyethyl 2-propenoate 0.00002 64-19-7 Acetic acid(impurity) 0.00001 % 9005-65-6 Sorbitan monooleate,ethoxylated 0.00001 % 9004-32-4 Sodium carboxymethylcellulose 0.00001 % 11138-66-2 Gum,xanthan 0.00001 % 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione <0.00001 % 7632-00-0 Sodium nitrite <0.00001 % 2634-33-5 1,2-benzisothiazolin-3-one <0.00001 % Total 100% •Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-partes. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cal 5 - 0 Q Well History File Identifier Organizing(done) wo-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: E Other: ❑ Other: BY: C--Maiia Date: I J7//5— /s/ mP Project Proofing BY: Maria Date: 1 ! /s/ mp7 Scanning Preparation 5 x 30 = / 50+ (),O = TOTAL PAGES 1 70 BY: 7/15'' (Count does not include cover sheet) �n iD Date: ' a, /s/ ' I Production Scanning Stage 1 Page Count from Scanned File: 171 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: ES NO BY: CM Date: (#7113-7 /s' /s/V 4 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: ES NO TOTAL PAGES:S\ Digital version appended by: Meredith Michal Date: 1 Ct I lis /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: oZo.J‘ Scanning is complete at this point unless rescanning is required. 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N 000 0 O 0 0 N N N'+' E IIS r+ E 1 A G >- as CO J 7 7 7 7 > 0 O O Ce Q N U)(/)U).jU)W o N 0 LE O 0.CO 0 m °' �° m CL J U NN 00 WN = N co z cc)- 0) Cea1 to N 0 O C) w W z d os 0) a I h V o o o J E m Z e vi °? co co co 0Qre cn dw3+ 0 E w G (n c U O �' 2 0 _ Lo C '1 co 0) 1 Ti CO O N '..N O - E w U � 0c U o J I p } Q Q M O fs O s Jd r N 0 E H 11z N O 5Z U O -;>C I' ail '.. COa O W > N y C c N E LO N O 1- E . co //M/� 0 R C 0) N 1 w V/ a I c C Q 0 ICC 0 r Y o a) c U n Q 1 i 1 ci z E L O 0 0 I U 5 M 0 III I 0 Z I LO lad csi o c 0 L0 N I 3 CO e >_ e co i.,...4 I 0 03 O ~ co c W E a O 6 r N N C) 0 O 1— c71 i d N d tee .0 w fA Q d o = ai ! d E E I z W 0 rc R0 .` 0 N 0 ''. O C H N Z c O 0 0 0 F- c Z c m 0 vi V .O+ N < O Q i� Q O 0 G C U 0 0 r fj 0 0) d 0) 0 E a C07 0 n 0 o- m O E d o o Z o O`13 o O o a) G 1 1 O 0 d 0. 2 J _ 0 a 0 0 0 0 3 1110 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil D ' Gas SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Ei • Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: '5/5/2015 215-006' 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99501 -4/12/2015 50-103-20704-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 188'FNL,734'FEL,Sec.22,T1ON, R7E, UM •4/30/2015 KRU 2L-316 Top of Productive Interval: 9. KB(ft above MSL): •155' 17. Field/Pool(s): 2258'FNL, 1965'FEL,Sec.24,T1ON, R7E, UM GL(ft above MSL): • 115' Kuparuk River Field/Tarn Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 765'FSL, 994'FEL,Sec.24,T1ON, R7E, UM 14975'MD/5521'TVD ADL 380052,380051 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 460917 y- 5927658 Zone- •14990'MD/5522'TVD 4600,4599 TPI: x- 470237 y- 5925546 Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 471200 y- 5923285 Zone- nipple @ 529'MD/529'TVD 1412'MD/1395'TVD 5. Directional or Inclination Survey: Yes • ❑✓(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 22. LogsOjs tained: 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 completi n,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontane potential, gamma ra caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evalu . relry,and perforation record. Acronyms may be used.Attach a separate page if necessary Elver r _;,."i"�--' MAY 29 2015 qi.l _,5 GR/Res/Neutron/Density A )GCC 7.7 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 165# A106B 40' 155' 40' 155' 20" driven 10.75" 45.5# L-80 39' 2518' 39' 2407' 13.5" 1160 sx ALC,220 sx DeepCRETE 7.625" 29.7# L-80 37' 11853' 37' 5308' 9.875" 1258 sx Clas G 7.625" 39# L-80 11853' 12187' 5308' 5367' 9.875" included above 4.5" 12.6# L-80 12013' 14975' 5336' 5521' 6.5" liner 24.Open to production or injection? Yes ❑ No E 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 12013' 11968'MD/5328'TVD perf pups from 12776'-14926'MD 5448'-5520'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 2 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised 5/2015 v 7-1._� q 2���� CONTINUED ONi�GE'2�� RBDM�S'��/, A16 2 �j 2015ubmit ORIGINIAL only 28.CORE DATA Conventional Cores Yes ❑ No ❑ Sidewall Cores: • ❑ No ❑✓ 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. none 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1412' 1395' Attach separate pages to this form,if needed,and submit detailed test information, including reports,per 20 AAC 25.071. C-80 2611' 2485' Campanian sand 2684' 2545' C-50 5539' 3707' C-40 7201' 4167' C-37 8054' 4401' T-7 9911' 4914' T-4.1 11221' 5190' T-3.1 12121' 5355' Top Bermuda 12510' 5415' Bermuda 12830' 5453' Formation at total depth: Bermuda 31. List of Attachments: summary of daily operations,wellbore schematic,final directional survey,cement reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. gM_ Contact: Steve Shultz @ 262-4297 Email: Steve.Shultzacontractor.cop.com Printed Name: G. L.Alvord Title: Alaska Drilling Manager Signature: 4,1_04._ Phone: 265-6120 Date: 5-0,61.2ous-- 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,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP PROD • 2L-316 r. O® ConocoPhillips Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) Ad Min(kKB) rvvx.Swnps 501032070400 TARN PARTICIPATING AREA PROD 91.07 14,023.98 14,990.0 ... Comment FUS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-316,520/20159.1849 AM SSSV:NIPPLE Last WO: 39.871 5/5/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date " --HANGER;350-- .163--1 ii- Last Tag: Rev Reason:NEW WELL smsmith 5/14/2015 ID Elf-Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(566) Set Depth(TVD)...Wt/Len(I .Grade Top Thread ._... ......... ............. _. CONDUCTOR 16 13.938 40.0 155.0 155.0 164.98 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread - SURFACE 10 3/4 9.950 38.8 2,518.0 2,407.1 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 50 Reducing;79.7 , INTERMEDIATE-7.625" 75/8 6,875 37.0 12,187.8 5,366.7 29.70 L-80 Hydri1563 x 8.52"@11747 -MdCONDUCTOR;40.0-155.0 • i. IL Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 4.5"LINER 41/2 3.958 12,013.0 14,975.1 5,521.1 12,60 L-80 IBT-m NIPPLE;529.5 _ Liner Details I Nominal ID t , Top(ftKB) Top(TVD)(ftKB) Top Incl("I Item Des Com (in) 12,013.0 5,336.0 79.71 HANGER BAKER HRD-E ZXP FLEX LOCK LINER HANGER 4250 SURFACE;38.8-2,510.0 - - 12,032.6 5,339.5 79.74 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4240 12,035.0 5,339.9 79.75 HANGER BAKER FLEX LOCK LINER HANGER 4.800 GAS LIFT;2,717.4 12,044.4 5,341.6 79.77 XO Reducing 5.5"Hyd 563 box x 4.5"Hyd 563 pin Crossover 4.800 Coupling GAS LIFT;5,161.0 12,592.5 5,426.5 82.14 SWELL BAKER SWELL PACKER"G" 3.958 PACKER 12,776.4 5,447.9 84.27 FRAC PORT BAKER FRAC SLEEVE#6(2.125"BALL,DRIFT ID 3.950 GAS LIFT;7,894.2 2.093") .�-- 12,954.4 5,464.1 85.71 SWELL BAKER SWELL PACKER"F" 3.958 • PACKER GAS LIFT;9,882.0 13,141.6 5,474.9 85.87 FRAC PORT FRAC SLEEVE#5(2.0'BALL,DRIFT ID 1.875") 3.940 ?;1 +• .! 13,321.7 5,491.0 84.81 SWELL BAKER SWELL PACKER"E" 3.958 • PACKER 13,506.0 5,504.5 86.65 FRAC PORT BAKER FRAC SLEEVE#4(1.875"BALL,DRIFT ID - 3.920 • p 1.750") GAS LIFT;11,858.8 13,684.7 5,512.3 88.40 SWELL BAKER SWELL PACKER"D" 3.958 T.,, I PACKER 13,867.9 5,516.7 88.92 FRAC PORT BAKER FRAC SLEEVE#3(1.750 BALL,DRIFT ID 3,940 SLEEVE;11,917.6 _ c4 1.625") GAUGE;11,941.6 `s 14,047.8 5,516.6 91.02 SWELL BAKER SWELL PACKER"C" 3.958 ? PACKER PACKER;11,967.6 14,192.2 5,514.4 90.66 FRAC PORT FRAC SLEEVE#2(1.625"BALL,DRIFT ID 1.5") 3.930 %O Threads;11,975.7 IP 14,372.3 5,513.1 89.83 SWELL BAKER SWELL PACKER"B" 3.958 NIPPLE;11,995.6 • PACKER 14,557.9' 5,514.6 89.25 FRAC PORT BAKER FRAC SLEEVE#1(1.5"BALL,DRIFT ID ' 3.930 LOCATOR;12,013.1 1.430") SUB;12,014.1 11• . i I 14,740.5 5,517.3 89.33 SWELL BAKER SWELL PACKER"A" 3.958 MULE SHOE;12,031.0 IlPACKER �l;�,/�' ; Tubing Strings III : Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. (TVD)(...Wl(Ib/ft) Grade Top Connection TUBING-4.5"x3.5" I 31/2 2.9921 35.01 12,032.3 5,339.5 Depth 5,339.5) 9.301 L-80 I EUE8rd } @ 79.68 J jt Completion Details Nominal ID INTERMEDIATE-7.625'z 8.52- s Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) @11747;37.9-12,187.6 35.0 35.0 0.00:HANGER CAMERON TUBING HANGER 3.900 79.7 79.7 0.36 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE 8rd pin 2.992 I 529.5 529.0 4.55 NIPPLE CAMCO DS NIPPLE 2.875 PERFP;12,778.4-12,77;.7 11,917.6 5,318.8 79.56 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813"DS PROFILE 2.810 (CLOSED) 11,941.8 5,323.2 79.58 GAUGE 'SLB GAUGE CARRIER 2.913 11,967.6 5,327.9 79.63 PACKER BAKER PREMIER PACKER 2.880 11,995.6 5,332.9 79.68 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 PERFP;13,141.6-13,143.9 I 1 12,013.1 5,336.0 79.71 LOCATOR BAKER SPECIAL SHEAR FLUTED NO-GO LOCATOR 3.000 12,014,1 5,336.2 79.71 SUB BAKER SPECIAL SHEAR LOCATOR SUB 3.000 12,031.0 5,339.2 79.74 MULE SHOE BAKER SPECIAL SHEAR TYPE WLEG 3.000 Perforations&Slots PERFP;13,506.0-13,508.2 ( ( Dens Top(ND) Bon(TVD) (shotslf Top(11613) Btm(kKB) (ftKB) (ftKB) Zone Date Shot I t) Type 12,776.4 12.778.7 5,447.9 5,448.1 5/2/2015 PERFP Frac Port Cent 13,141.6 13,144.0 5,474.9 5,475.1 5/2/2015 PERFP Frac Port 13,506.0 13,508.3 5,504.5 5,504.7 5/2/2015 PERFP Frac Port PERFP;13,867.9-13,8702 II t 13,867.9 13,870.2 5,516.7 5,516.8 5/2/2015 PERFP Frac Port 14,192.2 14,194.5 5,514.4 5,514.4 5/2/2015 PERFP Frac Port 14,557.9 14,560.2 5,514.6 5,514.7 5/2/2015 PERFP Frac Port 14,915.7 14,925.6 5,519.6 5,519.9 5/2/2015 PERFP Perf Pup PERFP;14,192.2-14,194.5 I I Mandrel Inserts St aB _. ' on Top(TVD) Valve Latch Port Sire TRO Run N Top(ftKB) (ftKB) Make Medal OD(in) Sery Type Type (ie) (psi) Run Date Com 1' 2,717.4 2,571.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 PERFP;14,557.9-14,5602 I I 2 5,161.0 3,602.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 0.000 0.0 5/4/2015 3 7,894.2 4,357.1 CAMCO KBMG 1 GAS LIFT DMY BK 4 9,882.0 4,905.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 _ 5 11,858.6 5,308.1 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0'5/4/2015 DCK-2 III PERFP;14,915.7-14,925.6 :r.I: 4.5-LINER;12,013.0-14,975.1 '`� KUP PO •2L-316 ConocoPhilhips i Well Attributes I Max Angle&MD TD Alaska,Inc. • Wellbore API/UWI Field Name Wellbore Status Ih1 net(°) MD(ftKB) Act Btm(ftKB) cam'-:: 501032070400 TARN PARTICIPATING AREA PROD 91.07 14,023.98 14,990.0 T ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-716,5/20/201512:52:26 PM SSSV:NIPPLE Last WO: 39.81 5/52015 Venice)schematic(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date HANGER;35.0--' - "' Last Tag: Rev Reason:NEW WELL smsmith 5/14/2015 Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Threatl .. .. .....CONDUCTOR 16 13.938 40.0 155.0 155.0 164.98 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...VA/Len(I...Grade Top Thread SURFACE 103/4 9.950 38.8 2,518.0 2,4071 4550 L-80 TSH 563 (p Casing Description OD(In) ID(In) Top(ftKB) 'Set Depth(ftKB) -Set Depth(TVD)... nLen(I...Grade Top Thread XD Reducing;79.7 x III W INTERMEDIATE-7.625" 75/8 6.875 37.0 12,187.8 5,366.7 29.70 L-80 Hydri1563 x 8.52'@11747 -,N.^.CONDUCTOR;400-156.0 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread 4.5"LINER 41/2 3.958 12,013.0 14,975.1 5,521.1 12.60 L-80 IBT-m NIPPLE;529.5 - Liner Details Nominal ID { Top(ftKB) Top(TVD)(ftKB) Top Incl(7) Item Des Com (in) 12,013.0 5,336.0 79.71 HANGER BAKER HRD-E ZXP FLEX LOCK LINER HANGER 4 250 SURFACE;38.8-2,518.0 12,032.6 5,339.5 79.74 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4240 GAS LIFT;2,717.4 12,035.0 5,339.9 79.75 HANGER BAKER FLEX LOCK LINER HANGER 4.800 12,044.4 5,341.6 79.77 XO Reducing 5.5"Hyd 563 box x 4.5"Hyd 563 pin Crossover 4.800 Coupling GAS LIFT;5,161.012,592.5 5,426.5 82.14 SWELL BAKER SWELL PACKER"G" 3.958 • PACKER t 12,776.4 5,447.9 84.27 FRAC PORT BAKER FRAC SLEEVE#6(2.125"BALL,DRIFT ID 3.950 GAS LIFT;7,894.2 '+ 2.093") Sj 12,954.4 5,464.1 85.71 SWELL BAKER SWELL PACKER"F" 3.958 i PACKER GAS LIFT;9,882.0 .f,I i 13,141.6 5,474.9 85.87 FRAC PORT FRAC SLEEVE#5(2.0"BALL,DRIFT ID 1.875") 3.940 13,321.7 5,491.0 84.81 SWELL BAKER SWELL PACKER"E" 3.958 PACKER ' " f'/ 13,506.0 5,504.5 86.65 FRAC PORT BAKER FRAC SLEEVE#4(1.875"BALL,DRIFT ID 3.920 r 1.750") GAS LIFT;11,6506 13,684.7 5,512.3 88.40 SWELL BAKER SWELL PACKER"D" 3.958 PACKER • SLEEVE;11,917.6 13,867.9 5,516.7 88.92 FRAC PORT BAKER FRAC SLEEVE#3(1.750 BALL,DRIFT ID 3.940 1.625") GAUGE;11,941.81 14,047.8 5,516.6 91.02 SWELL BAKER SWELL PACKER"C" 3.958 PACKER PACKER;11,9676 I, --- 14,192.2 5,514.4 90.66 FRAC PORT FRAC SLEEVE#2(1.625"BALL,DRIFT ID 1.5") 3.930 XO Threads;11,975.7 14,372.3 5,513.1 89.83 SWELL BAKER SWELL PACKER"B" 3.958 NIPPLE;11,955.6 PACKER 14,557.9 5,514.6 89.25 FRAC PORT BAKER FRAC SLEEVE#1(1.5"BALL,DRIFT ID 3.930 LOCATOR;12013.1 • 1.430") SUB;12,014.1 ' I IIM' 14,740.5 5,517.3 89.33 SWELL BAKER SWELL PACKER"A" 3.958 MULE SHOE;12,031.0 1 _ PACKER t ' Tubing Strings Tubing Description String Ma...ID(In) Top(5KB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-4.5"x3.5" 31/2 2.992 35.0 12,032.3 5,339.5 9.30 L-80 EUEBrd r @ 79.68 '•[ {' Completion Details INTERMEDIATE-7.625"x8.52* Nominal ID G11747;37.012,187.8 Top(NOB) Top(TVD)(ftKB) Top Incl(.) Item Des Com (in) 35.0 35.0 0.00 HANGER CAMERON TUBING HANGER 3.900 79.7 79.7 0.36 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE Sid pin 2.992 529.5 529.0 4.55 NIPPLE CAMCO DS NIPPLE 2.675 PERFP;12776.x12.778.7 { { 11,917.6 5,318.8 79.56 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813"DS PROFILE 2.810 (CLOSED) 11,941.8 5,323.2 79.58 GAUGE SLB GAUGE CARRIER 2.913 PERFP;13,141.6.13,143.9I 11,967.6 5,327.9 79.63 PACKER BAKER PREMIER PACKER 2.880 11,995.6 5,332.9 79.68 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 3.000[ 12,013.1 5,336.0 79.71 LOCATOR BAKER SPECIAL SHEAR FLUTED NO-GO LOCATOR 12,014.1 5,336.2 79.71 SUB BAKER SPECIAL SHEAR LOCATOR SUB 3.000 12,031.0 5,339.2 79.74 MULE SHOE BAKER SPECIAL SHEAR TYPE WLEG 3.000 Perforations&Slots PERFP;13,506.0.13,508.2 { [ Shot Dens T IftKB)) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 12,776.4 12,778.7 5,447.9 5,448.1 5/2/2015 PERFP Frac Port 13,141.6 13,144.0 5,474.9 5,475.1 5/2/2015 PERFP Frac Port PERFP;13,867.9.13,870.2 { 13,506.0 13,508.3 5,504.5 5,504.7 5/2/2015 PERFP Frac Port 13,867.9 13,870.2 5,516.7 5,516.8 5/2/2015 PERFP Frac Port _ 14,192.2 14,194.5 5,514.4 5,514.4 5/2/2015 PERFP Frac Port 14,557.9 14,560.2 5,514.6 5,514.7 522015 PERFP Frac Port 14,915.7 14,925.6 5,519.6 5,519.9 5/22015 PERFP Pert Pup PERFP;14,192.2-14,194.5 {I { Mandrel Inserts on St atl Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (In) (poll Run Date Com Y 2,717.4 2,571.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 PERFP;14,557.9-14,560.2 B { 2 5,161.0 3,602.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/4/2015 3 7,894.2 4,357.1 CAMCO KBMG 1 GAS LIFT DMY BK - 0.000 0.0 5/4/2015 0.0 5/4/2015 4 9,882.0 4,905.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 5 11,858.6 5,308.1 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 5/4/2015 DCK- ■ 2 PERFP;14,915.7-14,9256 {_t, 4.5"LINER;12,013.0.14,975.1 ►' f, " KUP ODD . 2L-316 ConocoPhillips 01 Alaska,Inc • HORIZONTAL-2L-316,5/20/2015 12 5226 PM Vertical schematic(actual) HANGER,35.0"" Elm ,,F-_. `t � Notes:General&Safety End Date Annotation . .• .... NOTE. XO Redwing;79 .7 1 'I w�._ M CONDUCTOR;40.0-155.0 I. !'pi BE NIPPLE;529.5 -- in SURFACE;38.8-2,518.0 I I GAS LIFT;2717.4 41 a GAS LIFT;5,161.0 • GAS LIFT;7,894.2 GAS LIFT;9,882.0 S. -u GAS LIFT;11,858.6 .,. SLEEVE;11,917.6 GAUGE;11,941.8 PACKER;119676 -- XO Threads;11,975.7 .� NIPPLE;11,95.6 5 ..-xT-, LOCATOR;12,013.1 SUB;12,014.1 MULE SHOE;12,031 0 I 1 :. ;,I I, INTERMEDIATE-7.625'z 8.52" X11747;37.0-12,187.8 PERFP;12,776 4-12.778.7 II PERFP,13,141.6.13,143.9 II PERFP;13.506.0.13,508.2 II PERFP;13867.9-13,870.2 II PERFP;14,192.2-14,194.5 IIl I PERFP;14,557.9-14,560.2 I I ■ PERFP;14,915.7-14,925.6 ,, 4.5"LINER;12,013.0-14975.1 • • Tarn 2L-316 Enterprise Grass Roots Topset,Horizontal Multi-Stage Frac'd Producer Final.Wellbore Schematic ConocoPhillips CAMERON MBS 5K with rt-V2" j 1 ) snor2sequi4 I. 16'62.6#EIW @ 106' 3"A"Canito OS I Nipple 2 575" 1= 13-112"Surface H&c.. -'529'M C , , ,• i• -- 2,717'611) Surface Casing: s 1F-3WID 1*-1 10-3i4"45.5#L-&i Hydril 563 2,518'MD i 2,40T TVD @ 34' 3'.,"x 1MAID 711841160 carapanian Top.•:•:•'•.•:•:•:•:,.•: .•.,;, -.....,-.. 2M4!Mo.0:$46.TVD)•::'•:: : : : L''4 ..••••••.•••..•TT•IT•T•.•T•.•. .• • .... . . . T. T . T T TT T T .. T .. T .. T. T. •TTSND 9-7/B"Intermediate Hale 3 li"x 1"IMMO -la'a PPG 1,61211D Nei Tubing: i.ieep up with 3-W 9.3#1-80 E UE8RD :)Hution 4-Y2"12.6#1-80 IBTM top joint to surface Top ct cement e 7.356'MD (-655above C37) Sm."'r kiligt wal. 11,1156160 it!ettOr§:TOP*P-.37.:i : -':•:•:•:::::::::::::;::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::: 8;171010,0:,'Ortb.ii::: :H:i• ::::::::::::::::::::::::::.::::: : :.: :•: :•:-: : :;:•-••:-: :-: :.: :•: :•:•:-:•. .•.•. Baker CM Sliding Sleeve CLOSED tv?3.1117"Campo'OS'Profile ..i -45'atove Packer -.3 Downhole Gauge-11,9SX7 MD 3 ,"Carrico 13 Nipple 2.75 • 35'x 7-51",Baker Premier Pecker ti-11,967'MD " * now)4,11,1195W D I II 7-51'x 4-1-i'Baker Flex Look Liner hanger ZXP liner 109 Par.ker o F Npflo 5''','-12.r"TC intermediate Casing Topset: t 7-518"29.7#1-80&bottom 330'TN•111)$$39#-ail i , Hydril 563 connections A ' 12,148'MD f 5,360'TVD ei.•80"' 6-112"Production Hole •_:c/i14"4„, „tri'..:0477,,, ..,..:::: : :::::••••••••••: ''-'•••:•••::::::.:':::::::::: :::iig. i.Z.:(3.*:/*.dilii.04ii.k•i:::::::.*:.::.::::,::,: :':::,:::::::]:::: PMP11?1:01)P.:fiYPti'::•:•••••:•:.:::•::•••••••••••••••• • ••:::::.::.•••:'•iiii:i:*:: ::• *::::::::•*:'•:.::::::::•: :i::•:'••:::::::: ::::::::: ::::•:: •••••••••:•:•••:•:•:•:::•:•:•:•:::::::::::::::::: •:•••••••••••:••••••:•:•:•:•:•:•:•:•:•:-..-:-:•:•:. '''--y- IIII El IIII ill A.: :•:•:-:•:•:•:•:•::•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:• KLASHIELD i:ii:i:iii•,:.:::::::::::::::::•:••„:",:•::: 9.8 PPG •:•:::::•:-:-:::::::::::::::•:::::•:•:•. . All :•:•:::•::::::::::::::::::::::•:•:::::::::::•:•........•::::::.:. ditbf I.,: iniii..: •,,t,„, 5,..::::....:.:::i::::.:i:.t.. ':':•••:-'•••••••••••••••••••••••••—•—•'::::::::::::.:.H.H..•••:•::i • • • • • • . • • • • - : : - :••.:•:•":•.:::::•:.:::::::::::: :•:•:•:•:•:•:•: Bermuda Pore Pressure : :•:•:•:•:•:•:•:•.•.•. •••••:•.,:lizi rir.::12..6 .MTV:-iwiTg:rings•:•.•:•:•.•.•.•.-.-.- :::::::•:•:•:::::: .--.8-82-10.7 ppg :iiiii]i:.::::•:•i••:••:::••:::::::ilnY.1$MD•t: W.TYP.:i'..:::::.iii:ii:::,::•::.:':: •:•:•:-::::::::::: • .__ ,,_ , , „ . * . ;•i]:::::.::::: ••••1•,i:•) :.:i:.:.::::::::::Ji';'::::':'::,*:.:.•,:•::.:::,-.. .. •••:. ::-::-::•:::::::::::: .,, " "! . - '000 pas) :::::::::::::::::::::::::::::*:•:•:•:•—• .. . .:.•.•.•.•:__,....,.•:,..... .7.7. . . . . . . .. ..:::::::::::::::: . . . . . . . . . . . . . . . . . . . . . . . .::::::::::::::::::::::•:•:::•::A4i966Miat5,621!.TVOi•E-i: ::•-: • ConocoPllillips Time Log & Summary N1ef/vieov Web Reporting Report Well Name: 2L-316 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 4/10/2015 9:00:00 PM Rig Release: 5/5/2015 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/09/2015 24 hr Summary RDMO 2L-316, Move modules and Sub down pad to position on next well. 00:00 07:30 7.50 0 MIRU MOVE RURD P Blow down interconnects on steam and water, separate modules and stomp out for separation. Fire all Cold Starts and switch to rig power. Disconnect High line power. Lower cattle chute, move BOP, MPD choke skid. Prep well house to move. 07:30 09:00 1.50 MIRU MOVE WAIT T Swap from rig power to Highline power and shut down cold starts. Gas leak on head flange behind 2L-316 conductor. Shut down rig move until gas bled down and flange was remounted and tested by DSO and DSL CPF-2. 09:00 12:00 3.00 MIRU MOVE MOB P Resume move. Stomping modules apart, place mats and continue moving casing module. Swap to Highline power to cold start engines. Continue to RD interconnects, set mats for movement. 12:00 00:00 12.00 MIRU MOVE MOB P Separate motor complex and pits, pull out with trucks away from Sub. Stage down pad and move mats for movement of modules and Sub. Crew change 14:00. Pull Sub off well and jockey down pad for alignment on 2L-316 well conductor. 34/10/2015 Continue rig move. Move over well and marry other modules to Sub. RU, MU interconnects, mate modules to rig power. Scope derrick and install cattle chute. Go to Highline power 1830. NU riser and lines. Rig move distance= 179'on well row. 00:00 07:00 7.00 0 MIRU MOVE MOB P Continue to walk sub over well, prep cellar with herculite and Hand-y-berm, lay rig mats for movement, attach sow and stage pit module near 2L-316. Shim and spot Sub,walk pipe shed around and line up to mate with Sub. Spot and shim pipe shed, pin pipe shed and Sub, stage pits, pump and motor complex on mats. Pagel of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 13:00 6.00 MIRU MOVE IRURD P PJSM, raise derrick, pin and secure. PJSM, skid rigfloor. Spot pit module, pump module and motor complex, plug in electrical interconnect. PJSM, lower C-section, PJSM, raise cattle chute. 13:00 18:30 5.50 MIRU MOVE RURD P Complete raising cattle chute and continue with interconnects. Prep derrick to scope, build hooch around diverter pipe in cellar,install cellar grating,get steam rolling around the rig, install steam traps,weld hand slip cart tracks on rig floor. Swap from cold starts to rig power. Swap to Highline power from rig power, check and balance rig power. 18:30 00:00 5.50 MIRU MOVE RURD P Spool drill line and pull pins for blocks and topdrive, Install bridal lines and yokes and scope derrick. Remove yokes and bridal lines. Bring riser to rig floor and NU riser, annular and pitcher nipple. Chink up Joe's box, RU flow line and flow line jets, Install Kelly hose, Load and prep 5"DP in casing shed. Rig accepted @ 2100 hrs 4/10/2015 04/11/2015 Continue to NU riser and slow lines, load pipe and strap in shed. PU 5"drill pipe and stand back 106 stands. Take Drilplex mud in pits. Perform Diverter test: Good. Witness waived by AOGCC rep John Crisp. PU and MU Clean-out BHA. 00:00 01:30 1.50 0 MIRU MOVE RURD P Continue to NU riser and flow lines, jet lines, install turnbuckles and secure riser and lines. Energize accumulator and function test; Good. Continue to load and prep 5"DP in casing shed. 01:30 02:00 0.50 MIRU MOVE SFTY P Pre-Spud for 2L-316 with rig team (both crews)per pre-spud documents and procedures. Crew change. 02:00 07:00 5.00 MIRU MOVE RURD P Continue to prep 5"DP, complete derrick inspection,secure diverter pipe, inspect top drive, gather and stage clean-out BHA components. 07:00 07:15 0.25 MIRU MOVE SFTY P PJSM to PU 5"drill pipe. 07:15 12:00 4.75 MIRU MOVE PULD P PU 5"drill pipe and stand back in derrick. Tag 47'in conductor, install 28'mouse hole in rotary table and PU DP. Crew change. 12:00 20:45 8.75 MIRU MOVE PULD P Continue to PU 5"drill pipe and stand back in derrick(Total of 106 stands). Test gas and methane alarms; Good. Page 2 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:00 1.25 MIRU MOVE 'PULD P Pull mouse hole and MU 6 stands of 5"HWDP with jars. Energize and test Cameron seals to 500 psi for 15 minutes CPAI rep witnessed. 22:00 22:30 0.50 MIRU MOVE BOPE P Perform Diverter sytem function test and drawdown. Accumulator=3000 psi,After function P=2050 psi, 200 psi recovery= 15 seconds, full recovery=67 seconds with 2 eletric and 2 air pumps. 6 bottle average= 2046 psi. Knife valve open= 10 seconds,Annular closed=33 seconds. Witness waived by AOGCC rep John Crisp. 22:30 23:00 0.50 MIRU MOVE RURD P Clean and clear rig floor. 23:00 00:00 1.00 MIRU MOVE BHAH P PU motor and set bend to 0°, MU bit to motor. Crew change. 04/12/2015 MU BHA#1. Fill lines and pressure test; good with no leaks. Clean out conductor to 155', spud and drill to 187' MD. POOH for drilling BHA#2. MU BHA#2, drill ahead to 558'mitigate pack-off and losses(172 BBL), heal loss and drill ahead to 931'MD. 00:00 01:00 1.00 0 47 MIRU MOVE BHAH P Continue to PU and MU Clean-out BHA#1 01:00 02:00 1.00 47 47 MIRU MOVE SEQP P Calibrate and test PVT Totco sensors, pressure test high pressure mud lines to 3500 psi with fresh water,test jet lines. 02:00 04:00 2.00 47 155 MIRU MOVE DRLG P Stage pumps and clean out conductor from 47'to 155'; bottom of conductor;600 GPM with 575 psi, 76%flow out. 50 RPM at 2K WOB with 3-5K torque. 04:00 04:30 0.50 155 187 SURFA( DRILL DDRL P (SPUD) Drill 13-1/2"hole w/0° motor from 155'to 187'. Pumping 600 GPM with 620 psi. Rotate 50 RPM with 1-2K ft-lbs of torque. PU wt 49K, SO wt 59K, Rot wt 53K. 04:30 05:00 0.50 187 42 SURFA( DRILL TRIP P Trip out from 187'to 42'for BHA change. 05:00 05:15 0.25 42 42 SURFA( DRILL SFTY P PJSM on handling BHA. 05:15 08:00 2.75 42 124 SURFA( DRILL BHAH P Inspect bit, Schlumberger directional driller and crew set bend on Schlumberger motor to 1.5°. Orient scribe of MWD with Gyro data. 08:00 09:00 1.00 124 187 SURFA( DRILL SRVY P Obtain gyro survey @ 124'and 187' while trip in the hole. Pumping 450 GPM with 515 psi. 09:00 09:30 0.50 187 213 SURFA( DRILL DDRL P Drill 13-1/2"hole w/1.5° motor from 187'to 213'. Pumping 450 gpm w/ 515 psi. Rotate 50 rpm w/1-2k ftlbs of torque. PU wt 67k, SO wt 50k, Rot wt 57k. 09:30 10:00 0.50 213 213 SURFA( DRILL TRIP P Pull out of the hole from 213', set back stand of HWDP. Continue to MU(3)7-1/4" NM drill collars, trip in from 124'to 213'. Page 3 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 213 1355 SURFA( DRILL DDRL P Directional drill 13-1/2"hole with 1.5° motor from 213'to 355'. Pumping 450 GPM with 575 psi on bottom, 515 psi off bottom. Rotate 50 RPM with 1-2K ft-lbs of torque.WOB 15K. PU= 64K, SO=73K, Rot=68K. Actual sliding time 0.76 hrs,Actual rotating time 0.53 hrs,Actual drilling time 1.29 hrs,total bit hrs 1.29 hrs. Jar hrs=0 hrs. KOP @ 250'(1045 hrs). Crew change. 12:00 15:00 3.00 355 558 SURFA( DRILL DDRL P Continue to drill from 355'to 558'at 450 GPM with 1150 psi, 50% FP, 50 RPM with 2K torque, 6K WOB. PU= 88K, S0=91K, Rot=88K. AST= 0.37,ART=0.97,ADT= 1.33 hours. 15:00 17:15 2.25 558 260 SURFA( DRILL BKRM T BROOH to clear pack-off and increased ECDs; 12.4 EMW observed. Loss of -150 BBL while working pipe and back-reaming to clear cuttings. Stage pumps up, but with BHA still in conductor ECD relief was not achieved. Stopped pumps to RIH. 17:15 17:45 0.50 260 558 SURFA( DRILL TRIP T Trip in the hole from 260'to 558'. Stage pumps to 650 GPM with 1150 psi, 50%FO, 70 RPM with 3K. Clear cuttings and gain ECD relief; 11.5 EMW. Losses slow to minimal observed. 17:45 22:30 4.75 558 885 SURFA( DRILL DDRL P Drill from 558'to 885'at 650 GPM with 1150 psi, 50%FP, 70 RPM with 3K torque, 11K WOB. PU=88K, SO=91K, Rot=88K. AST= 1.09, ART= 1.20,ADT=2.29 hours. 22:30 23:15 0.75 885 885 SURFA( DRILL WAIT T Wait on Super Suckers to arrive on location after two trucks were unable to load due to equipment breakdown. Resumed operations upon arrival. 23:15 00:00 0.75 885 931 SURFA( DRILL DDRL P Drill from 885'to 931'at 650 GPM with 1220 psi,44% FP, 70 RPM with 3K torque, 8K WOB. PU=88K, S0=91K, Rot=88K. AST= 1.09, ART= 1.20,ADT=2.29 hours. Crew change. Losses for day= 172 BBLs. 04/13/2015 Drill ahead in surface hole to 2479'MD,2376'TVD. 00:00 01:00 1.00 931 931 SURFA( DRILL CIRC T Unable to circulate at drill rate with Drilplex mud, thin mud add citric and 15 BBL water to active to achieve _prime. Establish circulation. 01:00 06:00 5.00 931 1,268 SURFA( DRILL DDRL P Drill from 931'to 1245'at 650 GPM with 1370 psi, 35%FO. 70 RPM with 2-3K torque. ECD= 10.76 EMW. PU= 100K, SO=97K, Rot=97K. Page 4 of 32 Time Logs • • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 1,268 1,720 SURFA( DRILL DDRL P Drill from 1268'to 1720'at 700 GPM with 1590 psi, 38%FO, 70 RPM with 4K torque, 19K WOB. PU= 104K, S0= 101K, Rot=102K. ECD= 10.60 EMW. AST=3.01,ART= 1.15,ADT=4.16 hours, Total Bit hours= 12.04, Jars hours=51.95. Crew change. Losses for tour=0 BBLs. 12:00 17:00 5.00 1,720 2,194 SURFA( DRILL DDRL P Drill from 1720'to 2194'at 700 GPM with 1640 psi, 33%FO, 70 RPM with 5K torque, 14K WOB. PU= 117K, S0= 109K, Rot=110K. ECD= 10.50 EMW. AST=2.95,ART= 1.59,ADT=4.54 hours,Total Bit hours= 16.58,Jars hours=56.49. Crew change. Losses for tour=0 'BBLs. 17:00 00:00 7.00 2,194 2,479 SURFA( DRILL DDRL P Drill from 2194'to 2479'at 700 GPM with 2040 psi, 36%FO, 80 RPM with 7K torque, 18K WOB. PU= 117K, S0= 109K, Rot=111K. ECD= 10.30 EMW. AST= 1.60,ART= 1.34,ADT=2.94 hours,Total Bit hours= 19.52, Jars hours=59.43. Crew change. No losses this tour. Losses to well= 172 BBLs. 04/14/2015 Drill to TD per Geologist at 2528' MD,2416'TVD. Circulate shakers clean while work our way up hole to 2198' (8 BU's). Monitor well-good, POOH on elevators f/2198'to 216'. PJSM, Lay down BHA#2, clear and clean floor. RU casing tools, dummy run csg hanger, PJSM, Run 10-3/4"casing to 2518' 00:00 00:30 0.50 2,479 2,528 SURFA( DRILL DDRL P Drill from 2479'to 2528'at 750 GPM with 2000 psi, 33%FO, 80 RPM with 4K torque, 20K WOB, ECD= 10.35 EMW. PU= 119K, SO= 110K. Rot= 110. AST=0,ART=0.50,ADT= 0.50 TD; 2528' MD,2416'TVD. 00:30 04:30 4.00 2,528 2,195 SURFA( CASING CIRC P Circulate BUs with 750 GPM with 2000 psi, 33%FO, 80 RPM with 4K torque,20K WOB, ECD= 10.35 EMW. PU= 119K, SO= 110K. Rot= 110. AST=0,ART=0.50,ADT= 0.50 Work through tight spot @ 2460'to 2420'several times. Circulated a total of 3090 bbls(8 BU's). 04:30 05:00 0.50 2,195 2,195 SURFA( CASING OWFF P Blow down top drive @ 2195'. Monitor well f/30 min-static. Slight drop due to hydrate gas breaking out. Rotate 20 rpm w/3-5k ft lbs of torque. Rot wt 115k. Page 5 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 08:30 3.50 2,195 216 SURFA( CASING TRIP P Pull out of the hole on elevators f/ 2195'to 216'. Monitor well on the trip tank. Work through tight spot @ 1580' several times, pulling 25k over. PU wt 105k, SO wt 103k. 08:30 08:45 0.25 216 216 SURFA( CASING SFTY P Pre job safety meeting on laying down BHA#2. 08:45 11:00 2.25 216 0 SURFA( CASING BHAH P Stand back a stand of 7-1/4" NM drill collars. Lay down BHA f/216'. 11:00 12:00 1.00 0 0 SURFA( CASING RURD P Clear floor of drilling tools. Clean floor. Drain stack, pull master bushings. 12:00 12:30 0.50 0 0 SURFA( CASING RURD P MU Cameron casing hanger on landing jt. -Make dummy run-Pull out&LD landing jt&hanger 12:30 13:45 1.25 0 0 SURFA( CASING RURD P RU to run casing-Install PS-21 slips w/inserts-MU 6'bail extenstions& elevatrors-MU Volant CRT 13:45 14:15 0.50 0 0 SURFA( CASING SFTY P Held PJSM w/CPAI, DDI,Tenaris and GBR reps-on running 10 3/4" dopeless casing 14:15 15:30 1.25 0 85 SURFA( CASING PUTB P MU shoe trackas follows:float shoe( Weatherford Model 303)2 jts 10 3/4" 45.5#L-80 Hydrl 563 csg-float collar(Ray Oil Tools)- 1 jt 10 3/4" 45.5#L-80 Hydril 563 csg to 85'-All connections made up w/BakerLoc- filled pipe&circ to check floats- Established baseline flow out parameters Installed bow spring centralizers on shoe track as follows: 2 on shoe jt- 10' up and over collar- 1 bow spring 10'below FC 15:30 20:30 5.00 85 1,606 SURFA( CASING PUTB P Cont. RIH w/10 3/4"45.5#L-80 Hydril 563 dopeless csg f/85'to 1606' (39 jts total in hole) Filling casing on the fly and top off every 5 jts. -Installed 1 bow spring centralizer per jt 20:30 21:15 0.75 1,606 1,689 SURFA( CASING CIRC P Break circ&wash down f/1606'to 1689'(jts#40&41 -Circ btms up staging pump up to 4 bbls/min @ 155 psi 17%FO-pumped 1353 stks-Mud wt in 9.9+ mud wt out 10.2 ppg 21:15 23:30 2.25 1,689 2,474 SURFA( CASING PUTB P Cont. RIH w/10 3/4"45.5#L-80 Hydrill 563 dopeless csg f/1689'to 2474'(60 jts total in hole)-installed bow spring centralizers 1 per jt to jt# 59 23:30 00:00 0.50 2,474 2,518 SURFA( CASING HOSO P MU Cameron fluted mandral hanger &landing jt. -wash down @ 3 bbls/min© 170 psi w/15%FO- Landing hanger on landing ring w/ shoe @ 2518.53' Page6of32 Time Logs * • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/15/2015 24 hr Summary Circ&cond. for cmt job-Cmt 10 3/4"csg w/399 bbls lead slurry&64 bbls tail slurry-Dispalced cmt w/10.0 ppg Drilplex mud-(didn't bump plug)floats held-RD from cmt job-NU&test Cameron wellhead-NU BOP &MPD system 00:00 02:00 2.00 2,518 2,518 SURFA( CEMEN-CIRCP Circulate and condition mud and hole f/cementing. Stage pumps up f/3 bpm w/165 psi, 3.5 bpm w/165 psi, 4 bpm w/175 psi, 5 bpm w/210 psi, 5.5 bpm w/171 psi, 6 bpm w/207 psi,6.5 bpm w/213 psi, 7 bpm w/ 225 psi. PU wt 140k, SO wt 110k. Recip pipe. Circulate 503.5 bbls. 02:00 02:30 0.50 2,518 2,518 SURFA( CEMEN-RURD P Blow down the top drive. Rig up cement hose. Establish circulation through cement hose. Circulate 6 bpm w/271 psi. 02:30 04:00 1.50 2,518 2,518 SURFA( CEMEN-CIRC P Continue circulating 7 bpm w/284 psi. ,while holding PJSM. Blow down the cement line to Dowell. 04:00 07:30 3.50 2,518 2,518 SURFA( CEMEN-CMNT P Dowell Pump 5 bbls of water to fill lines. Pressure test to 3500 psi-ok. Dowell batch up and pump 103 bbls of 10.6 ppg mudPush w/2 gal of red dye©avg 6 bpm w/final pressure of 188 psi. Dropped bottom plug. Mix lead cement(ALC)@ 11.0 pppg pumped 399 bbls @ 6.8 bbls/min- final pressure 494 psi(observed MudPush to surfce w/290 bbls of lead slurry pumped)Mixed tail cement(DeepCrete)© 12.0 ppg- pumped 63 bbls. @ 5 bbls/min. Final pressure 350 psi-Dropped top plug- Pumped 10 bbls water f/Dowell- Switched over to rig pumps and displaced cmt.w/229 bbls- 10.0 ppg Drillplex mud @ 8 bbls/min- slowed to 3 bbls/min for last 10 bbls of displacement final pressure 225 psi-Didn't bump plug-Full returns during job w/233 bbls 11.0 ppg cmt to surface-Recip. pipe until dropping top plug-loosing down wt. -CIP @ 0700 hrs. -Bled off pressure to check floats-Floats held 07:30 12:00 4.50 2,518 2,518 SURFA( CEMEN RURD P PJSM-ND diverter-RD Volant CRT -LD landing jt.-Flush surface stack and flow line w/black water-Blow down cmt line-Clean cmt valves- RD 10 3/4"single jt. elevators- remove 6'bail extenstions- Pull PS 21 slips 12:00 15:00 3.00 2,518 2,518 SURFA( CEMEN NUND P Pull riser-ND 21 3/4"annular-Slide joes flow box-Blow down TD-LD 17' riser&diverter Tee-Remove knife valve&24'jt of diverter pipe 15:00 16:45 1.75 2,518 2,518 SURFA( WHDBO NUND P NU 11"5K Cameron wellhead-test seals to 250&5000 psi for 15 mins. Page 7 of 32 Time Logs • 110' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 00:00 7.25 2,518 2,518 SURFA( WHDBO NUND P NU 13 5/8"BOP stack-Nipple up 2' adaptor spool-3'spool& 12.5'riser- slide in and Joes box-MU flow line- choke and kill lines-RU MPD system-shim stack in carrier f/NPD trip nipple-open ram doors& inspect cavities 04/16/2015 Cont. NU BOPE/MPD-RU &test BOPE-MU BHA#3-RIH to2262'-Slip&cut drill line-Wash down to 2384'(tag top of cmt)Circ btms up-RU&test csg to 3000 psi 00:00 03:00 3.00 0 0 SURFA( WHDBO MPDA P Cont. NU MPD trip nipple-Cont. inspect BOP blind/shear ram&top pipe ram-Install katch kan on RCD and Chink up 03:00 05:15 2.25 0 0 SURFA(WHDBO RURD P PJSM-MU test plug on 5"test plug -et test plug-RU test equipment- Function new annular element several times @ 800 psi- 1200 psi& 1500 psi 05:15 10:15 5.00 0 0 SURFA( WHDBO BOPE P PJSM-Test BOPE as follows: Tested annular to 250&2500 psi- Tested Upper pipe rams, Lower pipe rams, choke manifold valves, choke &kill line valves,4" Demco on kill line,5"TIW&Dart valves-Top drive IBOP's to 250&3500 psi-tested blind shear ram to 250&3500 psi- tested manual and hydralic chokes to 2000 psi-Performed accumulator recovery test-Start pressure 3000 psi-functioned rams, annular, & HRC's-1775 psi-start electric pump 200 psi gain in 35 secs.- 129 secs. back to 3000 psi-N2 bottles 2008 psi-Closing times annular 23 secs.-UPR 18 secs.-LPR 16 secs.-blind/shear 16 secs. -HRC's 2 secs. -All tests were performed w/ 5"test jt. -Test witnessed by Matt Herrera AOGCC 10:15 13:00 2.75 0 0 SURFA( WHDBO MPDA P PSJM-Tested MPD chokes-Pull triop nipple, Install test cap-fill linesw/watrer-Body test-gut line, chokes A&B&air valve to 250& 1000 psi 13:00 14:15 1.25 0 0 SURFA( WHDBO RURD P Blow down test equipment, choke& kill lines, MDP choke skid, remove test cap&install trip nippple, pull test plug-install wear bushing 10" ID 14:15 16:45 2.50 0 744 SURFA( CEMEN-BHAH P MU BHA#3-9 7/8"bit, power drive, Ecoscope,Telescope-Install RA sources in MWD-3 NMflex DC's- float/saver sub w/non ported float, float sub w/non ported float, 12 jts HWDP,jars, 5 jts HWDP to 744' 16:45 17:45 1.00 744 1,690 SURFA( CEMEN-PULD P RIH w/BHA f/744'to 1690'-picking up 5" DP f/pipe shed(30 jts) Page 8 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:30 0.75 1,690 I 1,690 SURFA( CEMEN-DHEQ P Shallow pulse test MWD w/450 gpm @ 880 psi w/16%FO-(Good test) Blow down TD 18:30 19:30 1.00 1,690 2,262 SURFA( CEMEN-PULD P Cont. RIH f/ 1690'to 2262'-picking up 5" DP f/shed(18 jts.)installed ghost reamer on top of jt#36 19:30 21:00 1.50 2,262 2,262 SURFA( CEMEN'SLPC P Cut and slip 71'drill line-calc. block height 21:00 21:30 0.50 2,262 2,262 SURFA( CEMEN SVRG P Service top drive, blocks&crown 21:30 21:45 0.25 2,262 2,384 SURFA( CEMEN COCF P Wash down f/2262'to 2384'@ 4 bbls/min @ 210 psi w/6%FO- tagged top of cmt 21:45 22:15 0.50 2,384 2,356 SURFA( CEMEN CIRC P Circ btms up @ 450 gpm @ 930 psi -pull back to 2356'-blow down TD 22:15 22:30 0.25 2,356 2,356 SURFA( CEMEN'RURD P RU to test casing 22:30 00:00 1.50 2,356 2,356 SURFA( CEMEN PRTS P Pressue test 10 3/4"casing to 3050 psi for 30 mins.-lost 350 psi in 10 mins. -lost 40 psi during the last 20 mins of test-bled off pressure- Notified drilling engineer-Re-test casing to 3000 psi 04/17/2015 Finish csg test-Drill out shoe track&20' new hole-Change over to LSND mud-Perform FIT to 16.8 ppg- Install MPD bearing on std of 5" DP&Std back in derrick-Wash down f/2451'to 2548'-Drill 9 7/8"hole f/ 2548'to 3283 00:00 00:30 0.50 2,356 2,356 SURFA( CEMEN PRTS P Pressure test 10 3/4"casing to 3050 psi for 30 mins.-lost 50 psi in 10 mins.-good test. 00:30 01:00 0.50 2,356 2,356 SURFA( CEMEN-RURD P Rig down testing equipment. Blow down choke and kill line. 01:00 01:15 0.25 2,356 2,384 SURFA( CEMEN-CIRCP Establish parameters: PU wt 116k, SO wt 103k, Rot wt 110k. Rotate 50 rpm w/5k torque. Pumping 450 gpm w/905 psi--15%flow out. Obtain SPR's @ 2351'MD(2204'TVD):#1 mud pump:20/30 strokes=60/80 psi.#2 mp 20/30 strokes=60/80 psi w/9.7+mud weight @ 0100 hrs.. Page 9 of 32 Time Logs ill Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 04:15 3.00 2,384 2,433 SURFA( CEMEN-COCF P Tag cement @ 2384' MD. Drill cement f/2384'to 2392'pumping 450 gpm w/950 psi--15%flow out. Drill w/5k weight on bit, rotate 50 rpm w/ 5k ft lbs of torque. Drill top plug @ 2392' MD pumping 500 gpm w/1200 psi--17%flow out. Drill w/5k weight on bit, rotate 50 rpm w/5-6k ft lbs of torque. Con't to drill cement f/2392'-2433' top of float collar)pumping 600 gpm w/1470 psi-19%flow out. Drill w/ 5-7k weight on bit, rotate 50 rpm w/ 5k ft lbs of torque. Star bottom plug by setting 30k weight on bit.Then drill wiper rubber and float collar f/2433'to 2435' pumping 450 gpm w/935 psi-15% flow out. Drill w/5-15k weight on bit, rotate 50 rpm w/5k ft lbs of torque. Drill cement from 2435'to top of Weatherford float shoe @ 2516'. Drill float shoe f/2516'to 2518' pumping 450 gpm w/826 psi-15% flow out. Drill w/6-8k weight on bit, rotate 60 rpm w/6-8k ft lbs of torque. Clean out rat hole f/2518'to 2528' (2411'TVD). 04:15 07:15 3.00 2,433 2,528 SURFA( CEMEN-DRLG P Star bottom plug by setting 30k weight on bit. Then drill wiper rubber and float collar f/2433'to 2435' pumping 450 gpm w/935 psi-15% flow out. Drill w/5-15k weight on bit, rotate 50 rpm w/5k ft lbs of torque. Drill cement from 2435'to top of Weatherford float shoe @ 2516'. Drill float shoe f/2516'to 2518' pumping 450 gpm w/826 psi-15% flow out. Drill w/6-8k weight on bit, rotate 60 rpm w/6-8k ft lbs of torque. Clean out rat hole f/2518'to 2528' (2411'TVD). 07:15 08:00 0.75 2,528 2,548 SURFA( CEMEN-DDRL P Drill 9-7/8"hole w/Schlumberger Rotary steerable f/2528'to 2548' (2432'TVD), pumping 600 gpm w/ 1150 psi-20%flow out. Drill w/4-14k weight on bit. Rotate 60 rpm w/5k ft lbs of torque. ADT= .26 hrs,ART= .26 hrs, Bit hrs .26,Jar hrs 60.14. 08:00 08:30 0.50 2,548 2,548 SURFA( CEMEN-CIRC P Circulate bottom's up while reciprocating f/2539'to 2527'and rotating 60 rpm w/5k ft lbs of torque. Pumping 600 gpm w/1652 psi-20% flow out. PU wt 122k, SO wt 106k, Rotating weight 111k, Rot torque 4k ft lbs. Page 10 of 32 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:30 08:45 0.25 2,548 2,548 SURFA( CEMEN-SFTY P Pre job safety meeting on displacing 9.8 ppg Drilplex spud mud to 9.6 ppg LSND mud. 08:45 09:15 0.50 2,548 2,548 SURFA( CEMEN DISP P Pump 65 bbls Hi vis spacer @ 326 gpm w/488 psi-13%flow out, chase w/new 9.6 ppg LSND mud. Rotate and reciprocate 60 rpm w/4k ft lbs of torque from 2539'to 2527'. Pumping 600 gpm w/1377 psi-19%flow out. Pumped 254 bbls. 09:15 09:45 0.50 2,548 2,451 SURFA( CEMEN-TRIP P Obtain SPR's, Pull out of the hole f/ 2548'to 2451'. Blow down the top drive. 09:45 10:00 0.25 2,451 2,451 SURFA( CEMEN-OWFF P Monitor the well-static. 10:00 10:45 0.75 2,451 2,451 SURFA( CEMEN-FIT P Pre job safety meeting.Then rig up to perform FIT. Pressure up to 900 psi w/9.6 ppg mud, shoe @ 2518.53' MD(2407'TVD), lost 115 psi in 10 min. after shutting down. FIT to 16.8 ppg. Pumped .8 bbls, returned .66 bbls after test. 10:45 11:00 0.25 2,451 2,451 INTRM1 DRILL MPDA P Pre job safety meeting on installing MPD bearing on a stand of 5"drill pipe. 11:00 11:45 0.75 2,451 2,451 INTRM1 DRILL MPDA P Install bearing on stand#40, set back stand w/a clamp under the bearing section. 11:45 12:00 0.25 2,451 2,548 INTRM1 DRILL REAM P Ream/Wash down f/2451'to 2548', pumping 450 gpm w/850 psi, rotate 60 rpm w/4k ft lbs of torque. SPR's @2531' MD 2419'TVD w/9.6 ppg LSND @ 0900 hrs #1 20/30 SPM 120/140 psi #2 20/30 SPM 100/140 psi Page 11 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 19:00 7.00 2,548 2,962 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/2548'to 2960' MD 2759'TVD ADT-5.8 hrs ECD- 10.2 ppg Footage-412' WOB 3 k RPM 90 GPM 650 @ 1520 psi String wt. PU 122 SO 112 ROT 119 Torque on/off btm.-6 k Total bit hrs. 5.8 hrs Total jar hrs. 65.21 hrs SPR's @ 2541'MD 2427'TVD @ 12:10 hrs. #1 20/30 spm 120/140 psi #2 20/30 spm 120/140 psi Total losses for tour=39 bbls 19:00 00:00 5.00 2,962 3,283 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/2960'to 3283' MD 2953'TVD ADT-3.03 hrs. ECD-10.40 ppg Footage-323' WOB 3.5 k RPM 125 GPM 700 @ 1740 psi w/24% FO String wt. PU 128 SO 116 ROT 119 Torque 6 to 7 k Total bit hrs. 8.83 hrs Total jar hrs 68.24 hrs Pumped Hi-vis sweep @ 3017'- Observed 50%increase in cuttings 34/18/2015 Drilled 9 7/8"hole f/3283'to 5504' 00:00 06:00 6.00 3,283 3,790 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3283'to 3790' MD 3202.18'TVD ADT-4.86 hrs. ECD- 10.42 ppg Footage-507' WOB 6 k RPM 135 GPM 700 @ 1868 psi w/24% FO String wt. PU 133 SO 114 ROT 120 Torque on/off btm. 9/7 k ft/lbs Total bit hrs. 13.69 hrs Total jar hrs 73.1 hrs Pumped Hi-vis sweep @ 3500'- Observed 75%increase in cuttings Page 12 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 3,790 4,347 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3790'to 4347' MD 3375'TVD ADT-3.81 hrs ECD-10.42 ppg Footage-557' WOB 8 k RPM 135 GPM 700 @ 2140 psi w/24% FO String wt. PU 141 SO 112 ROT 120 Torque on/off btm.-10/9 k ft/lbs Total bit hrs. 17.50 hrs Total jar hrs. 76.91 hrs. Pumped Hi-Vis sweep©4000'w/30 %increase in cuttings SPR's©4246'MD 3347'TVD @ 10:58 hrs # 1 20/30 spm 150/190 psi #2 20/30 spm 150/180 psi 12:00 14:00 2.00 4,347 4,530 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4347'to 4530' MD 3426'TVD ATD- 1.18 hrs ECD- 10.6 ppg Footage- 183' WOB9k RPM 135 GPM700@ 2150 psi w/24% FO String wt. PU 141 SO 112 ROT 120 Torque on/off btm.- 10/6 k ft/lbs Total bit hrs 18.68 hrs Total jars hrs. 78.09 hrs Pumped Hi-Vis sweep @ 4510'w/15 %increase in cuttings SPR's @ 4431' MD 3399'TVD @ 12: 45 hrs #1 20/30 spm 160/200 psi #2 20/30 spm 150/190 psi 14:00 14:30 0.50 4,530 4,530 INTRMI DRILL MPDA P Remove trip nipple-Install RCD bearing 14:30 18:00 3.50 4,530 4,814 INTRMI DRILL DDRL P Drilled 9 7/8" hole w/RSS f/4530'to 4814'MD 3505'TVD ADT-2.31 hrs. ECD- 10.69 ppg Footage-284' WOB 6 k RPM 135 GPM 700 @ 2250 psi w/24%FO String wt. PU 145 SO 110 ROT 122 Torque on/off btm.-11/7 k ft/lbs Total bit hrs. 20.99 hrs. Total jar hrs. 80.4 hrs. Page 13 of 32 Time Logs 11111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 4,814 5,504 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4814'to 5504' MD 3696'TVD ADT-4.79 hrs. ECD- 10.97 ppg Footage-690' WOB 15 k RPM 135 GPM 700 @ 2480 psi w/25% FO String wt. PU 149 SO 109 ROT 123 Torque on/off btm.- 13/9 k ft/lbs Total bit hrs. 25.78 hrs. Total jar hrs. 85.19 hrs Pumped Hi-Vis sweep @ 5006'w/10 %increase in cuttings 04/19/2015 Drilled 9 7/8"hole f/5504'to 7358'-Repair electrical connection on TD 00:00 06:00 6.00 5,504 6,045 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5504'to 6045' MD 3843'TVD ADT-4.72 hrs. ECD- 11.12 ppg Footage-541' WOB 10 k RPM 150 GPM 700 @ 2480 psi w/24% FO String wt. PU 154 SO 116 ROT 122 Torque on/off btm.-10/8 k ft/lbs Total bit hrs. 30.5 hrs. Total jar hrs. 89.91 hrs SPR's @ 5854'MD 3793'TVD @ 0350 hrs. #1 20/30 spm 150/200 psi #2 20/30 spm 160/190 psi 06:00 12:00 6.00 6,045 6,560 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6045'to 6560' MD 3992'TVD ADT-3.7 hrs. ECD- 11.24 ppg Footage-515' WOB 9 k RPM 160 GPM 700 @ 2827 psi w/23% FO String wt. PU 166 SO 116 ROT 128 Torque on/off btm.- 10/8 k ft/lbs Total bit hrs. 34.2 hrs. Total jar hrs. 93.61 hrs Page 14 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 6,560 7,090 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6560'to 7090' MD 4136'TVD ADT-4.33 hrs. ECD- 11.32 ppg Footage-530' WOB 11 k RPM 160 GPM 700 @ 2680 psi w/23% FO String wt. PU 159 SO 121 ROT 135 Torque on/off btm.- 11/7 k ft/lbs Total bit hrs. 38.53 hrs. Total jar hrs. 97.94 hrs Pumped Hi-Vis sweep @ 6805'w/40 %increase in cuttings. Drilled f/ 6805'to 6900'@ 100'/hr. SPR's @ 6613'MD 4006'TVD @ 12:35 hrs. #1 20/30 spm 180/240 psi #2 20/30 spm 180/235 psi 18:00 21:00 3.00 7,090 7,358 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7090'to 7358'MD 4207'TVD ATD-2.1 hrs. ECD-11.42 ppg Footage-268' WOB 13 k RPM 160 GPM 700 @ 2795 psi w/23% FO String wt. PU 160 SO 121 ROT 133 Torque on/off btm.- 13/8 k ft/lbs Total bit hrs.40.63 hrs Total jasr hrs. 100.04 hrs. 21:00 00:00 3.00 7,358 7,358 INTRM1 DRILL RGRP T Top drive connection @ interconnect at draw works arc flashed and burnt connector-Circ @ 450 gpm @ 1390 psi and work pipe while repairing electrical connection 34/20/2015 Finish repair TD connection-Drilled 9 7/8"hole f/7358'to 9263' 00:00 03:00 3.00 7,358 7,358 INTRM1 DRILL RGRP T Finish repairing top drive electrical connection 03:00 03:30 0.50 7,358 7,358 INTRM1 DRILL SVRG P Service top drive. Page 15 of 32 Time Logs • , Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 7,358 7,585 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/7358'to 7585' MD 4272'TVD ATD-2.25 hrs. ECD- 11.31 ppg Footage-227' WOB7k RPM 160 GPM 700@ 2779 psi w/20% FO String wt. PU 159 SO 123 ROT 143 Torque on/off btm.- 11/8 k ft/lbs Total bit hrs. 42.88 hrs Total jar hrs. 102.29 hrs. Dilution of 290 bbls @ 7465' SPR©7559' MD 4264'TVD w/MW of 9.6+. MP 1 20/30 spm 210/260, MP2 @ 20/30 200/250. 06:00 12:00 6.00 7,585 8,160 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7585'to 8160' MD 4430'TVD ATD-3.67 hrs. ECD- 11.31 ppg Footage-227' WOB 14 k RPM 160 GPM 700 @ 2886 psi w/20% FO String wt. PU 165 SO 126 ROT 140 Torque on/off btm.-11/7 k ft/lbs Line up to circ thru MPD chokes-35 psi @ drilling rate Closing MPD chokes on connections beginning @ 7935'to monitor annulus for pressure while drilling Iceberg formation Total bit hrs. 46.55 hrs Total jar hrs. 105.96 hrs. SPR @ 8128' MD 4420'TVD w/ MW of 9.7+. MP 1 20/30 spm 200/250, MP2 @ 20/30 200/240. 12:00 12:15 0.25 8,160 8,160 INTRM1 DRILL OTHR T Swap to rig engines/generators to accomadate CPF 2 Electricians Line maint. 12:15 18:00 5.75 8,160 8,790 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/8160'to 8790'MD 4606'TVD ADT-4.02 hrs ECD- 11.29 ppg Footage-630' WOB 14 K RPM 160 GPM 700 @ 3000 psi w/22% FO String wt. PU 171 SO 135 ROT 144 Torque on/off btm.- 13/8 k ft/lbs Total bit hrs. 50.57 hrs Total jar hrs. 109.98 hrs Closing MPD chokes on connections &monitor annulus-Max. pressure 2 psi Page 16 of 32 Time Logs Date From "To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 8,790 9,263 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/8790'to 9263' MD 4735'TVD ADT-3.03 hrs ECD- 11.20 ppg Footage-573' WOB 7 K RPM 160 GPM 700 @ 2820 psi w/22% FO String wt. PU 185 SO 127 ROT 149 Torque on/off btm.-15/10 k ft/lbs Total bit hrs. 53.6 hrs Total jar hrs. 13.01 hrs. Closing MPD chokes on connsctions to monitor annulus-max. pressure 5 psi Max gas observed 550 units SPR's @8811'MD4612'TVD @ 19:05 hrs. #1 20/30 spm 180/230 psi #2 20/30 spm 170/220 psi 04/21/2015 Drilled 9 7/8"hole f/9263'to 12008' 00:00 06:00 6.00 9,263 9,927 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/9263'to 9927' MD 4917'TVD ADT-4.33 hrs ECD-11.09 ppg Footage-664' WOB9K RPM 160 GPK700@ 3010 psi w/23% FO String wt. PU 190 SO 130 ROT 149 Torque on/off btm.-15/10 k ft/lbs Total bit hrs. 57.93 hrs Total jar hrs. 117.34 hrs SPR's @ 9357'MD 4761'TVD @ 00:52 hrs #1 20/30 spm 220/260 psi #2 20/30 spm 210/250 psi 06:00 12:00 6.00 9,927 10,550 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/9927'to 10550' MD 5075'TVD ADT-4.25 hrs. ECD-11.23 ppg Footage-623' WOB 15 K RPM 160 GPM 700 @ 3040 psi w/22% FO String wt. PU 200 SO 129 ROT 158 Torque on/off btm.-15/10 k ft/lbs Total bit hrs. 62.18 hrs. Total jar hrs. 121.59 hrs Page 17 of 32 Time Logs Date From To Dur S. DepthE. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 10,550 11,250 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/10550' to 11250'MD 5195'TVD ADT-4.25 hrs ECD- 11.26 ppg Footage-700' WOB 14 K RPM 160 GPM 700 @ 2970 psi w/23%FO String wt. PU 209 SO 128 ROT 160 Torque on/off btm.-20/12.5 k ft/lbs Total bit hrs.66.43 hrs Total jar hrs. 125.84 hrs Max. gas 107 units SPR's @ 10681'MD 5093'TVD @ 13:11 hrs. #1 20/30 spm 220/260 psi #2 20/30 spm 200/260 psi 18:00 00:00 6.00 11,250 12,008 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/11250' to 12008'MD 5335'TVD ADT-4.69 hrs. ECD- 11.39 ppg Footage-758' WOB 15 K RPM 160 GPM 700 @ 3030 psi w/22% FO String wt. PU 215 SO 127 ROT 160 Torque on/off btm.- 19/13 k ft/lbs Total bit hrs. 71.12 hrs Total jar hrs. 130.53 hrs Max gas 340 units 04/22/2015 Drilled 9 7/8"hole to 12197'TD-Pump sweep&Circ hole clean-BROOH to 4340'-Strip out of hole w/MPD to 2451'-Circ btms up 00:00 02:45 2.75 12,008 12,197 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/12,008 to 12,197'MD-5368'TVD ADT-1.63 hrs. ECD- 11.24 ppg Footage- 189' WOB 16 K RPM 160 GPM 700 @ 3259 psi w/20% FO String wt. PU 2225 SO 127 ROT 162 Torque on/off btm.-20/12 k ft/lbs Total bit hrs. 72.75 hrs Total jar hrs. 132.16 hrs. SPR's @ 12,102'MD 5352'TVD @ 01:05 hrs w/9.8 ppg #1 20/30 spm 260/330 psi #2 20/30 spm 260/320 psi Page 18 of 32 Time Logs 4110 41110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:30 0.75 12,197 12,197 INTRM1 CASING CIRC P Circ&recip. f/12,197'to 12,097'@ 700 gpm w/160 rpm-Pump up survey @ 12,104'& 12,195' SPR's @ 12,197'MD 5368'TVD @ 03:10 hrs w/9.9 ppg #1 20/30 spm 290/350 psi #2 20/30 spm 290/340 psi 03:30 04:45 1.25 12,197 12,197 INTRM1 CASING CIRC P Pumped 40 bbls Hi-Vis sweep @ 700 gpm w/160 rpm-recip. pipe f/ 12,195'to 12,097' Observed 12%increase in cuttings @ shakers 04:45 08:00 3.25 12,197 11,904 INTRM1 CASING CIRC P Cont. circ 3 X btms up @ 700 gpm w/160 rpm racking back 1 std DP every btms up f/ 12,195'to 11,904' 08:00 08:30 0.50 11,904 11,904 INTRM1 CASING OWFF P Monitor well-Well static 08:30 12:00 3.50 11,904 10,195 INTRM1 CASING BKRM P BROOH @ 700 gpm @ 3122 psi w/ 160 rpm @ 14/15 k torque pulling @ 1,000 to 1600 ft/hr f/11904'to 10,195' 12:00 21:15 9.25 10,195 4,340 INTRM1 CASING BKRM P BROOH @ 700 gpm @ 2350 psi w/ 160 rpm w/7 k torque-pulling @ 1600'/hr f/10,195'to 4340' 21:15 21:45 0.50 4,340 4,340 INTRMI CASING OWFF P Monitor well-blow down TD-line up MP#1 to injection line&MPD skid- Well static Ghost reamer inside csg 21:45 23:45 2.00 4,340 2,451 INTRM1 CASING TRIP P POOH on elevators f/4340'to 2451'- stripping through RCD holding 70 psi on annulus while pulling&30 psi while in slips-BHA into csg 23:45 00:00 0.25 2,451 2,451 INTRM1 CASING CIRC P Circ surface casing volume @ 700 gpm @ 2090 psi w/40 rpm @ 3.5 K torque-recip. pipe f/2451'to 2360' 04/23/2015 Finish circ btms up-Monitor well-Pull RCD bearing-Set trip nipple-POOH-LD BHA-RU to run csg-Ran 7 5/8"csg to 4362'-Circ btms up @ 4263' 00:00 00:30 0.50 2,451 2,451 INTRMI CASING CIRC P Cont. Circ btms up @ 700 gpm @ 2056 psi w/40 rpm w/4 k torque 00:30 01:15 0.75 2,451 2,451 INTRM1 CASING OWFF P Blow down TD-Monitor well 30 mins. @ 10 3/4"shoe-well static 01:15 03:00 1.75 2,451 2,451 INTRMI CASING MPDA P Pull RCD bearing out of RCD& remove f/DP-Install trip nipple- blow down MPD choke skid 03:00 04:00 1.00 2,451 775 INTRM1 CASING TRIP P POOH on elevators f/2451'to 775'( top of BHA) 04:00 04:30 0.50 775 775 INTRM1 CASING OWFF P Monitor well-SIMOPS change out slip inserts PJSM on LD BHA w/ DD/MWD&rig crew Well static 04:30 06:45 2.25 775 0 INTRM1 CASING BHAH P Pull and LD BHA-17 jts. HWDP, jars, float subs, NMflex DC's, Pulled sources f/MWD, LD MWD, EcoScope,PD flex collar, PD receiver sub, Power drive, &bit. Page 19 of 32 Time Logs 4110 Date From . To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:30 1.75 0 0 INTRM1 CASING RURD P Clear rig floor of BHA tools-Drain BOP stack-Pull wear bushing 08:30 09:30 1.00 0 0 INTRM1 CASING WWWH P MU stack washer-Flush stack& wellhead-LD stack washer-Blow down TD 09:30 10:00 0.50 0 0 INTRM1 CASING RURD P Drain stack-MU hanger&landing jt -make dummy run w/hanger-break out hanger(leave on rig floor) LD landing jt. 10:00 11:00 1.00 0 0 INTRM1 CASING RURD P RU to run csg.-install 6"bail extensions,elevators, slip inserts, & MU XO to floor safety valve 11:00 12:30 1.50 0 0 INTRM1 CASING BOPE P Set test plug-Change top pipe rams to 7 5/8"-Test rams&annular to 250&3500 psi w/7 5/8"test jt.-Pull &LD test jt. &test plug-blow down kill line 12:30 13:00 0.50 0 0 INTRM1 CASING RURD P RU Volant CRT 13:00 19:30 6.50 0 2,486 INTRM1 CASING PUTB P Ran 7 5/8"39#TN-110&29.7#L-80 Hydril 563 as follows: Float shoe Ray Oil Tools sliver bullet)2 jts. 39# TN-110-Float collar(Weatherford)2 jts. 39#TN110-(all connections made up w/Baker Lock -Filled pipe &checked floats- 1st 3 jts. had Testco hydroform cent. crimped on# 1 10'f/shoe,#2 10'f/pin,  10' up f/float collar)6 jts. 39#TN110 to 438.21'( 10 jts total in hole)-XO sub 7 5/8"39#Hyd 563(P)x 29.7# Hyd 563(B)-1 jt,29.7#L-80-(2)7 5/8"29.7#L-80 Hyd 563 pup jts. 9.84'& 14.83')-46 jts.29.7#L-80 csg to 2486' (57 jts total in hole) Installed 1 Hydroform centralizer per jtf/#4to#56 39#TN-110 Hydril 563 made up to 22,200 &29.7#L-80 Hydril 563 made up to 11,900 19:30 20:00 0.50 2,486 2,486 INTRM1 CASING CIRC P Establish circ&circ casing volume- Staging pump up to 6 bbls/min-ICR @ 2 bbls/min 50 psi-FCR @ 6 bbls/min 195 psi 20:00 23:30 3.50 2,486 4,362 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hyd 563 csg f/2486'to 4362'( 101 jts total in hole)Slack off weights trending down 23:30 00:00 0.50 4,362 4,362 INTRM1 CASING CIRC P Establish circ&stage pumps up to 7 bbls/min-ICR @ 3 bbls/min 250 psi FCR @ 7 bbls/min 330 psi- Pumped 2250 strokes-Mud wt in& out @ 9.8 ppg 04/24/2015 Cont. RIH w/7 5/8"csg f/4263'to 5436'-Circ-RIH w/csg f/5436'to 8000'-Circ-RIH w/csg f/8000'to 12148'-MU Hanger&landing jt&land csg w/shoe @ 12,187'-Circ&condition for cmt job Page 20 of 32 Time Logs • �' Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 02:00 2.00 4,362 5,436 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hyd. 563 csg f/4362'to 5436'(126 jts total in hole)installed 1 hydroform centralizer per jt f/# 102 to#109 MU torque 11.9 K T&D model trending down 02:00 03:00 1.00 5,436 5,436 INTRM1 CASING CIRC P Establish circ&circ btms up+ (2172 stks)staging pump up to 6 bbls/min @ 500 psi-Mud wt in 9.8- Mud wt out 9.9 03:00 08:30 5.50 5,436 8,000 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hyd 563 csg f/5436'to 8000'-MU torque 11.9 k 08:30 10:00 1.50 8,000 8,000 INTRM1 CASING CIRC P Establish circ&circ btms up+ staging pump to 6 bbls/min @ 500 psi(4172 stks pumped) Mud wt in 9.8 mud wt out 9.9 10:00 12:00 2.00 8,000 9,026 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hyd 63 csg f/8000'to 9026'(210 jts. total in hole) 12:00 20:30 8.50 9,026 12,148 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hyd 563 csg f/9026'to 12,148'(283 jts total in hole)-Installed 1 Hydroform centralizer on every other jt. f/#226 to#282 20:30 21:00 0.50 12,148 12,187 INTRM1 CASING HOSO P MU Cameron fluted mandrel hanger &landing jt. -Landed hanger in wellhead w/casing shoe @ 12,187.76'-Float collar @ 12,097.25' Final SO wt 107 21:00 23:15 2.25 12,187 12,187 INTRM1 CEMEN-CIRC P Establish circ&stage pump up to 7 bbls/min-Circ btms up and condition mud for cmt job-ICP 2 bbls/min @ 245 psi-FCP 7 bbls/min @ 685 psi-Pumped 5500 stks Recip. pipe f/12187'to 12,172'while circulating 23:15 23:45 0.50 12,187 12,187 INTRM1 CEMEN-RURD P Release CRT-Blow down TD- Engage CRT-MU cmt line 23:45 00:00 0.25 12,187 12,187 INTRM1 CEMEN CIRC P Re-establish circ-stage pump up to 7 bbls/min @ 645 psi-Circ& condition mud for cmt job-Recip. pipe f/12,187 to 12,172'while circulating 34/25/2015 Cont. circ&condition mud for cmt job-PJSM-Cemented 7 5/8"casing w/252 bbls 15.8 ppg Gas GASBLOK slurry-Displaced w/545 bbls 9.8 ppg LSND mud-bumped plug-ck. floats Good-CIP @ 0540 hrs.-RD-set&test pack-off- 00:00 02:00 2.00 12,187 12,187 INTRM1 CEMEN CIRC P Cont. Circ&condition mud @ 7 bbls/min @ 670 psi w/8%FO-PU wt 245 SO wt 110 -Recip. pipe f/12,187'to 12,172'-Mud wt in&out 9.8 ppg YP- 19 Page 21 of 32 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 06:00 4.00 12,187 12,187 INTRM1 CEMEN-CMNT P Cemented 7 5/8"casing as follows: Dowell Pump 5 bbls of CW100 to fill lines. Pressure test to 4000 psi-ok. Followed by 45 bbls of CW100 @ 5.5 bpm with 600 psi,followed by 53 bbls of Mud Push II @ 5 bpm with 600 ps. Shut down bleed off and drop bottom plug followed by 252 bbls of GASBLOK 15.8 ppg cement 6 bpm with 600 psi. Shut down and bleed off and drop top plug followed with 10 bbls of water at 6 bpm with 190 psi. Swap over to rig and displace cement with 545 bbls of 9.8+ LSND mud at 6 bpm ICP= 150 psi while reciprcating pipe FCP= 1300 psi, started to lose down weight at 3500 stks into displacement, landed hanger on seat and reduced rate to 3 bpm at 5300 stks into displacement ICP=960 psi, FCP=1117 psi, bumped plug at 5413 stks, increase pressure to 1500 psi for 5 min, bleed off pressure and checked floats- Good.-CIP @ 0540 hrs. Lost 42 bbls fluid during dispalcement 06:00 08:00 2.00 12,187 12,187 INTRM1 CEMEN-RURD P RD cementing and casing equipment -Clean&clear rig floor-Drain stack --Break out landing jt&LD- Remove bail extensions,elevators, clean 4" Demco valves on rig floor& mud pits 08:00 09:00 1.00 12,187 12,187 INTRMI CEMEN-WWSP P PU&run 7 5/8"pack-off-test to 250 &5000 psi for 10 mins. -Good test 09:00 13:15 4.25 12,187 12,187 INTRM1 CEMEN PULD P PJSM-PU&set mouse hole in rotary table-LD 5"drill pipe f/derrick -LD doubles&singles-storing 36 doubles in tub A&B-Cont.to load 4"DP in pipe shed long side 13:15 18:00 4.75 12,187 12,187 INTRM1 CEMEN PULD P Cont. LD 5"drill pipe singles via mouse hole SIMOPs-RU Little Red Services to OA to freeze protect-Tested lines to 4000 psi-Pumped 88 bbls fresh water to flush @ 3 bbl/min @ 5000 psi-followed by 71 bbls Isotherm NT @ 2 bbls/min @ 1300 psi-Shut in OA&RD Little Red-Flush&test MPD choke skid to 250& 1000 psi- Blow down choke skid 18:00 23:15 5.25 12,187 12,187 INTRM1 CEMEN PULD P Finish LD 5"drill pipe f/derrick 23:15 00:00 0.75 12,187 12,187 INTRMI CEMEN PULD P RU&pick up 4"DP building stands via mouse hole&std. back in derrick 04/26/2015 PU 4" DP-RU&Test BOPE-MU BHA#4-RIH w/BHA#4-picking up 4" DP to 3489'-Trouble shoot& replace draworks drive motor A encoder Page 22 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 INTRM1 CEMEN-PULD P PU 4"DP&Build stds in mouse hole&std. back in derrick(34 stds) 04:00 05:30 1.50 0 0 INTRM1 CEMEN-RURD P PJSM-Change out saver sub to XT-39(SIMOPS)-bring BHA tools to rig floor 05:30 08:00 2.50 0 0 INTRM1 WHDBO RURD P PJSM-PU 4"test jt. &set test plug -Fill stack, lines&choke manifold w/water-Conduct body test-Good 08:00 13:00 5.00 0 0 INTRM1 WHDBO BOPE P Tested BOPE as follows:Tested Upper&lower pipe rams,Annular, choke manifold valves, choke&kill line valves, TD IBOP's, TIW&Dart valves(4"&3 1/2")4"Demco on kill line, blind/shear rams to 250&3500 psi for 5 mins.Tested manual& Super choke to 2000 psi Tested upper, lower pipe rams& annular w/4"-4 1/2"&3 1/2"test jts. -Performed accunulator recovery test-Start pressure 3000 psi-after function 1700 psi-90 secs to build 200 psi&back to full charge in 96 secs. -N2 bottles 1925 psi Closing times-Annular 23 secs. UPR 18 secs. LPR 17 secs. -HCR choke&kill 2 secs. Witnessing of test waived by Bob Noble AOGCC 13:00 14:00 1.00 0 0 INTRM1 WHDBO RURD P RD test equipment-Pull test plug- set wear bushing-blow down lines 14:00 17:30 3.50 0 516 INTRM1 CEMEN-BHAH P MU BHA#4-bit(Hycalog SKH 513M)Power drvie w/NonPorted float, Power Drive Receiver sub,PeriScope, ImPulse, SonicScope, adn VISION,Float sub w/non ported float, 3 NM flexDC's, #2 Float sub w/non ported float,XO, 4 jts 4" HWDP, Jars,4 jts. HWDP- total BHA 515.89' 17:30 18:30 1.00 516 1,528 INTRM1 CEMEN-PULD P Change slip inserts-RIH w/BHA#4 f/515.89'to 1528'-Picking up doubles of 4" DP f/pipe shed 18:30 19:00 0.50 1,528 1,528 INTRM1 CEMEN DHEQ P Shallow pulse test MWD 2 220 gpm @ 1170 psi-Good test-Blow down top drive 19:00 21:30 2.50 1,528 3,489 INTRM1 CEMEN-PULD P Cont. RIH w/BHA#4 f/1528'to 1907'(picking up doubles)f/pipe shed- RIH f/1907'to 3489'-picking up singles f/pipe shed-Fill pipe every 2000' 21:30 22:00 0.50 3,489 3,489 INTRM1 CEMEN-SVRG P Service&inspect crown,top drive,& blocks 22:00 00:00 2.00 3,489 3,489 INTRM1 CEMEN RGRP T Troulbe shoot, inspect&replace draworks drive motor A encoder SIMOPs-Housekeeping&PM's Page 23 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/27/2015 24 hr Summary Continue repair on draworks drive motor A encoder. Slip&cut drill line. Test casing to 3000 psi; Good. Continue RIH with BHA#4 from 3489'to 11240'. Turned Sonic tool on @ 6999'and perform Sonic logging on trip in. 00:00 02:30 2.50 3,489 3,489 INTRM1 CEMEN-RGRP T Cont.trouble shoot draworks drive motor A encoder-SIMOPS-work on work orders and housekeeping 02:30 04:30 2.00 3,489 3,489 INTRMI CEMEN SLPC P PJSM-Slip&cut drill line 101'- Calibrate Totoc,Amphion, &MWD block height&hook load 04:30 05:00 0.50 3,489 3,489 INTRMI CEMEN SVRG P Servic TD, blocks, &traveling assembly 05:00 08:30 3.50 3,489 3,489 INTRM1 CEMEN RGRP T Cont. trouble shoot draworks drive motor A encoder-SIMOPS-work on work orders and housekeeping 08:30 09:45 1.25 3,489 3,489 INTRM1 CEMEN-PRTS P PJSM-RU&test 7 5/8"casing to 3000 psi fopr 30 mins. -Good Test- Bleed off pressure&RD 09:45 14:15 4.50 3,489 6,999 INTRM1 CEMEN-PULD P Cotnt. RIH w/BHA#4 f/3489'to 6999'-picking up 4"DP f/pipe shed -filling pipe evry 2000' 14:15 14:45 0.50 6,999 6,999 INTRM1 CEMEN-CIRCP MU TD&stage pump to 220 gpm @ 1620 psi-Down link to MWD to start Sonic tool-Blow down TD 14:45 00:00 9.25 6,999 11,240 INTRM1 CEMEN DLOG P Cont. RIH w/BHA#4 f/6999'to 11,240'-picking up 4"DP f/pipe shed @ 900'/hr-logging w/Sonic tool for cmt bond-Fill pipe evey 2000' 04/28/2015 Continue to perform Sonic logging to 11997'. Drill shoe track and 20'new hole. Perform FIT to 16.0 EMW. Swap mud system over to KLA-Shield. Obtain SPR and Drill ahead in 6 1/2"production section to 12523'. 00:00 02:30 2.50 11,240 11,997 INTRM1 CEMEN DLOG P Cont. RIH w/BHA#4 f/11,240'to 11,997'-picking up 4" DP f/pipe shed logging @ 900'/hr-logging w/ Sonic tool for cement bond-Fill pipe every 2000' 02:30 06:30 4.00 11,997 12,061 INTRMI CEMEN-DRLG P M/U TD stand#122 , obtain parameters before tagging cement. Stage pumps to 200 GPM, 1750 PSI, 10% F/O, 60 RPM, 14K TQ, PU= 190K, S0=67K, ROT= 115K- 12K TQ.Wash down tagging cement @ 12,051'MD. Drill cement @ 200 GPM, 1760 PSI, 10% F/O,60 RPM, 14K-15K TQ, 10K WOB. Tag cement plugs @ 12,095'. Drill plugs and Float Collar @ 200 GPM, 1860 PSI, 70 RPM, 15K TQ,6-10% F/O, 3-10K WOB. Drill out Shoe @ 12,185'MD, 200 GPM, 40-60 RPM, 15-16K TQ, 1865 PSI, 9% F/O, 5-15K WOB, through Shoe @ 12,187'. Page 24 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:00 1.50 12,187 12,217 INTRM1 CEMEN-DDRL P Drill 6 1/2" Production hole f/12,187' MD t112,217' MD, 230 GPM, 2447 PSI, 12%F/O, 70 RPM, 15K TQ,8K WOB, Off BTM 2246 PSI, PUW 232K, SOW 55K, ROT 115K, 12K TQ. ART 1.73,ADT 1.73. Bit 1.73, Jars75.13. 08:00 10:00 2.00 12,217 12,217 INTRM1 CEMEN-CIRC P CBU while Recip and rotate f/12,217', t112,097'@ 200 GPM, ICP 1997 PSI, 11% F/O, 70 RPM, 14K TQ. Circulate and condition mud in and out to 9.8 ppg, FCP 1750 PSI. 10:00 11:30 1.50 12,217 12,184 INTRM1 CEMEN-FIT P Pull into casing racking back 1 STD, t/12,184' MD. Conduct FIT to 16.0 ppg EMW, 1730 PSI with 9.8 ppg MW. 11:30 13:00 1.50 12,217 12,217 PROD1 DRILL DISP P Displace well with 9.8 ppg KLA-SHIELD while rotating and recip f/12,217' t/12,178'@ 200 GPM, 1997 PSI, 11%F/O, 70 RPM, 14K TQ. 13:00 14:00 1.00 12,217 12,280 PROD1 DRILL DDRL P Drill 6 1/2"Production hole(/12,217' t/12,280' MD, 5,381'TVD, @ 240 GPM,2053 PSI, 9%F/O, 80 RPM, 12K TQ, 11K WOB, ECD 10,79, Off BTM 2080 PSI, PUW 175K, SOW 79K, ROT 115K, 11K TQ. 14:00 15:00 1.00 12,280 12,280 PROD1 DRILL OTHR P Pull into casing t/12,183'MD, clean pits,shaker beds and troughs. 15:00 17:00 2.00 12,280 12,185 PROD1 DRILL CIRC P CBU while rotating and recip f/12,185' t/12,280'@ 203 GPM, 1580 PSI, 8% F/O, 50 RPM, 10K TQ. Rack back 1 STD t/12,185'. 17:00 18:00 1.00 12,185 12,185 PROD1 DRILL MPDA P B/D TD, drain stack below RCD Head. Pull RCD trip nipple and install RCD drilling bearing. 18:00 18:30 0.50 12,185 12,280 PROD1 DRILL SRVY P Obtain SPR and Surveys from 12,185' to 12,280'. SPR at 12280' MD, 5381'TVD, MW= 9.8 ppg #1; 20/30 SPM =420/650 psi #2; 20/30 SPM =440/666 psi 18:30 00:00 5.50 12,280 12,523 PROD1 DRILL DDRL P Drill 6 1/2" Production hole from 12,280'to 12523'at 250 GPM with 2235 psi, 6%FO, 100 RPM with 12K torque, 12K WOB, ECD= 10.95. PU= 178K, S0=78K, Rot= 115K. ART/ADT=3.65 hours, Total bit hour=5.38,Jar hours=78.79 hours. OAP=570 psi. No losses this tour. Crew change. 04/29/2015 Continue to drill ahead in 6 1/2"production section from 12523'to 14937'. Increase mud weight from 9.8 to 10.0 ppg Page 25 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 12,523 12,942 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 12,523'to 12,942'at 250 GPM with 2198 psi, 5-7%FO, 120 RPM with 13K torque, 13K WOB, ECD= 11.02. PU= 190K, S0=80K, Rot= 120K. ART 3.66,ADT 3.66, Bit 9.04, Jars 82.45. Drilling MPD choke PSI = 10, Max Choke shut in PSI = 15. 06:00 12:00 6.00 12,942 13,510 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 12,942'to 13,510'at 255 GPM with 2362 psi, 5-7% FO, 150 RPM with 13K torque, 15K WOB, ECD= 11.1. PU= 185K, SO=70K, Rot= 125K. ART 3.86,ADT 3.86, Bit 12.90, Jars 86.31. Drilling MPD choke PSI = 10, Max Choke shut in PSI =8, Max Gas 1500 units. 12:00 18:00 6.00 13,510 14,276 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 13,510'to 14,276'at 256 GPM with 2489 psi, 6% FO, 150 RPM with 14K torque, 8K WOB, ECD= 11.28. PU= 190K, SO=72K, Rot= 114K.ART 3.86,ADT 3.86, Bit 12.90,Jars 86.31. Drilling MPD choke PSI = 10, Max Choke shut in PSI = 10, Max Gas 1500 units. 18:00 00:00 6.00 14,276 14,937 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 14276'to 14,937'at 253 GPM with 2480 psi,6%FO, 150 RPM with 16K torque, 16K WOB, ECD= 11.40. PU= 189K, SO=74K, Rot= 109K. ART/ADT= 8.01, Bit 20.91, Jars 94.32. Max Gas 3200 units. Weight up system from 9.8 to 10.0 ppg. Crew change. OAP=540 psi. No losses for day. 04/30/2015 Drill to TD at 14990' MD, 5521'TVD. BROOH with drilling parameters to shoe, circulate casing clean and POOH with MPD pressure schedule. 00:00 00:30 0.50 14,937 14,990 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 14937'to 14,990'TD section at 253 GPM with 2480 psi,6% FO, 150 RPM with 16K torque, 16K WOB, ECD= 11.40. 00:30 02:15 1.75 14,990 14,990 PROD1 CASING CIRC P Circulate and condition mud until 10.0 ppg in and out. Connection gas at 10.0 ppg 1230 units dropping to 350 units average background gas. 02:15 02:45 0.50 14,990 14,990 PROD1 CASING OWFF P Observe well for flow: Static. 02:45 07:45 5.00 14,990 12,183 PROD1 CASING BKRM P BROOH with drilling rates of 250 GPM with 2450 psi, 150 RPM with 14K torque into shoe. Page 26 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 12:00 4.25 12,183 12,183 PROD1 CASING CIRC P Circulate casing clean at the shoe at 200 GPM with 1591 psi 7%FO, 50 RPM, 9K torque. Pump 40 BBL High Vis sweep followed by 3X BU, total of 1380 BBL pumped. Stage tools and liner pups to rig floor. Crew change. OAP=460 psi. Losses for tour=0 12:00 12:30 0.50 12,183 12,090 PROD1 CASING CIRC P Continue circulating casing clean in the shoe at 200 GPM with 1591 psi 4%FO, 50 RPM, 9K torque. 12:30 13:15 0.75 12,090 12,090 PROD1 CASING OWFF P Observe well for flow with closed chokes and open port on stack; Static. Obtain rotary parameters with 10 RPM =7.6K torque. PU= 161K, SO=83K, Rot= 110K. 13:15 14:00 0.75 12,090 12,090 PROD1 CASING CIRC P Pump 40 BBL 12 PPG dry job, blow down top drive, line up on injection line through choke skid. Establish circulation across the top. 14:00 20:45 6.75 12,090 2,508 PROD1 CASING TRIP P Strip out of the hole with pressure on MPD per pressure schedule from 12090'to 2508'. Drop rabbit prior to tripping. 20:45 21:45 1.00 2,508 2,508 PROD1 CASING CIRC P Circulate out dry job, pump 106 BBL. 21:45 22:45 1.00 2,508 610 PROD1 CASING TRIP P Strip out of the hole with pressure on MPD per pressure schedule from 2508'to 610'. 22:45 23:45 1.00 610 610 PROD1 CASING MPDA P Change out MPD bearing to trip nipple. 23:45 00:00 0.25 610 610 PROD1 CASING TRIP P RU hole fill line, stand back last stand of DP and change out slips. Crew change, OAP=460 psi. No losses for day. 05/01/2015 Continue to POOH and LD BHa#4. RU to run liner per detail and running order, verify jewelry and running order from shed. RU and run 4 1/2" L-80 12.6#IBTm liner to the 7 5/8"shoe, 12175'. Circulate 2x BU. 00:00 02:00 2.00 610 600 PROD1 CASING TRIP P Pull out of hole to HW and stand back HWDP, PU HW for push pipe and pull out to BHA. 02:00 04:00 2.00 600 0 PROD1 CASING BHAH P PUll out of hole with BHA#4, pull sources, LD BHA per DD and MWD. 04:00 05:30 1.50 0 0 PROD1 CASING BHAH P Clean and clear floor of BHA components,flush stack and stage casing equipment to rig floor. Flush MPD skid. 05:30 06:00 0.50 0 0 COMPZ CASING SVRG P Service TD, PS-21 slips. 06:00 07:15 1.25 0 0 COMPZ CASING RURD P RU casing equipment to run 4 1/2" L-80 12.6#IBTm liner. 07:15 07:30 0.25 0 0 COMPZ CASING SFTY P PJSM for running liner with Baker rep, Doyon casing rep, and crew. 07:30 12:00 4.50 0 2,289 COMPZ CASING PUTB P Run 4 1/2"L-80 12.6#IBTm liner per running order and detail to 2289'with make-up torque of 4K ft lbs topping off every 10. Crew change 10:00. Page 27 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 2,289 2,919 COMPZ CASING PUTB P Continue to run 4 1/2" L-80 12.6# IBTm liner per running order and detail to 2919'with make-up torque of 4K ft lbs. 13:00 14:00 1.00 2,919 2,967 COMPZ CASING OTHR P PU pup, change out slip inserts, and elevators. MU liner hanger to 2967'. Mix and place PAL mix. 14:00 14:30 0.50 2,967 2,967 COMPZ CASING CIRC P Circulate liner volume 47 BBL, 126 GPM with 220 psi. Blow down top drive. 14:30 15:00 0.50 2,967 3,350 COMPZ CASING RUNL P Continue to run 4 1/2" L-80 12.6# IBTm liner per running order and detail to 3350'with make-up torque of 4K ft lbs. 15:00 15:30 0.50 3,350 3,350 COMPZ CASING CIRC P Pump 10 BBL 12 PPG dry job , blow down top drive. 15:30 19:45 4.25 3,350 12,175 COMPZ CASING RUNL P Continue to run 4 1/2" L-80 12.6# IBTm liner per running order and detail to 12175'with make-up torque of 4K ft lbs. 19:45 00:00 4.25 12,175 12,175 COMPZ CASING CIRC P Circulate 2X BU staging pumps to 168 GPM with 720 psi, 6%FO. Pumped 779 BBL total. Monitor well and pump 10 BBL 12 PPG dry job dry job and spot inside 4.5"liner to keep drill pipe from running back over during trip in,. Crew change at 20:00. 05/02/2015 Continue running 4 1/2"liner to TD, pump DP volume,drop ball and set liner and release,test annular to 3000 psi; Good. RU and displace well to 10.1 ppg brine. LD 4"drill pipe. 00:00 02:15 2.25 12,175 14,990 COMPZ CASING RUNL P RIH with 4 1/2" Liner with 4"DP from 12,175'to 14,990'and tag and set down 10K. Running speed 90 fpm. Obtain SOW every stand and monitor well displacement. at the trip tank. 02:15 03:15 1.00 14,990 14,974 COMPZ CASING CIRC P Circulate DP volume at 14,974',2 bpm, 550 psi 1% F/O.At 2.5 bpm, 660 psi, 1%F/O.At 3 bpm, 770 psi, 3%F/O. PUW 188K, SOW 90K. 03:15 04:00 0.75 14,974 12,011 COMPZ CASING PACK P At 14,974'drop 1.75"Phenolic ball and chase it at 2.5 bpm, 715 psi,2% F/O.At 2.5 bpm, 835 psi, 3% F/O. Seat ball at 911 stks, 91.5 bbls. Pressure up to 1800 psi,40K SOW to 14,982'. PU to 14,967. Rotate 15 rpm, 7K TQ 130K RTW. Set down 56K, 14,980'and P/U to 14,965'. Release PU= 165K. 04:00 04:15 0.25 12,011 12,011 COMPZ CASING SFTY P PJSM for testing ZXP Liner hanger. 04:15 05:00 0.75 12,011 12,011 COMPZ CASING PRTS P Close top pipe rams and pump down IA. Pressure to 3000 psi at 4 bbls. Hold pressure for 30 minutes on chart recorder. Test good, bled back 4.2 bbls. Page 28 of 32 •Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 07:15 2.25 12,011 11,993 COMPZ WELLPF DISP P PU to 11,993'and displace mud with 10.1 PPG brine. pump 60 BBL High Vis spacer and chase with 10.1 PPG brine at 6 BPM with 1300 psi, 6% FO, FCP= 1095 psi. Pump total 552 BBL. 10.1 brine in and out. 07:15 08:00 0.75 11,993 11,993 COMPZ WELLPF OWFF P Observe well for flow: Static. SIMOPs; clean mud troughs. 08:00 11:00 3.00 11,993 12,036 COMPZ WELLPF CIRC P LD one double and circulate BU with 6 BPM with 1000 psi, 5%FO, circ total of 552 BBL while reciprocating. 11:00 11:15 0.25 12,036 11,785 COMPZ WELLPF PULD P LD 4"DP; doubles from 12036'to 11973'. LD 4" HWDP singles from 11973'to 11785'. Proper fill observed via trip tank. 11:15 11:45 0.50 11,785 11,785 COMPZ WELLPF SVRG P Service and inspect top drive. 11:45 12:00 0.25 11,785 11,537 COMPZ WELLPF PULD P Continue to LD 4"HWDP singles from 11785'to 11537'. Crew change. No losses for tour. 12:00 12:45 0.75 11,537 10,859 COMPZ WELLPF PULD P LD 4"HWDP singles from 11537'to 11859'. 12:45 14:30 1.75 10,859 7,757 COMPZ WELLPF PULD P LD 4" DP singles from 11859'to 7757'. Total 52 doubles laid to bins. 14:30 18:00 3.50 7,757 3,708 COMPZ WELLPF PULD P LD 4" DP singles from 11859'to 7757'. 18:00 21:00 3.00 3,708 45 COMPZ WELLPF PULD P LD 4" DP singles from 3708'to Baker running tools. 21:00 21:45 0.75 45 0 COMPZ WELLPF BHAH P Change out slip inserts, LD running tools per Baker rep. clear and clean rig floor. Install slip inserts. 21:45 23:00 1.25 0 3,699 COMPZ WELLPF TRIP P RIH with 39 stands from derrick to 3699'. 23:00 00:00 1.00 3,699 2,751 COMPZ WELLPF PULD P LD 4" DP from 3699'to 2751'. Crew change. OAP=260 psi. 05/03/2015 Continue to LD of 4" DP. RU run 3 1/2"9.3#L-80 EUE 8rd tubing per detail and running order to 9971'. 00:00 02:00 2.00 2,751 0 COMPZ WELLPF PULD P LD 4" DP from 2751'out of the hole. 02:00 02:30 0.50 0 0 COMPZ WELLPF RURD P Clean and clear floor,wash stack. 02:30 03:00 0.50 0 0 COMPZ RPCOM RURD P Stage equipment to the rigfloor to run tubing. 03:00 06:00 3.00 0 0 COMPZ RPCOM RURD P R/U to run 3 1/2"upper completion. 06:00 06:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM, running 3 1/2"completion. 06:15 12:00 5.75 0 2,160 COMPZ RPCOM PUTB P Run 3 1/2"upper completion to 2,160'with SLB Gauge Mandrel. PT Gauge connection to 5000 psi and install Cannon clamps every connection.Test Tec wire every 30 joints.TQ connections to 25 FT/LBS. 12:00 18:00 6.00 2,160 5,727 COMPZ RPCOM PUTB P Continue running 3 1/2"upper completion from 2,160'to 5,727'.TQ connections to 2500 FT/LBS. Install Cannon clamps every connection.Test Tech wire every 30 joints. Page 29 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 5,727 9,971 COMPZ RPCOM PUTB P Run 3 1/2"upper completion from 5,727'to 9971'.Torque connections to 2500 FT/LBS. Install Cannon clamps every connection.Test Tech wire every 30 joints. ,Crew change. 35/04/2015 Continue running 3 1/2"tubing to liner top at 12013'tubing measure, land and space out. MU space out string and spot corrosion inhibited brine. PT tubing and IA: Good. Install BPV,test; Good and ND BOPE. Begin wellhead work and testing. 00:00 02:00 2.00 9,971 11,084 COMPZ RPCOM PUTB P Continue running 3 1/2"upper completion from 9971'to 11084'. Torque connections to 2500 FT/LBS. Install Cannon clamps every connection.Test Tech wire every 30 joints. 02:00 02:30 0.50 11,084 11,084 COMPZ RPCOM PUTB T LD joint 349 and replace with joint 292,same length, no tally changes needed. Seal ring moved during make up and galled threads. 02:30 04:00 1.50 11,084 12,013 COMPZ RPCOM PUTB P Continue running 3 1/2"upper completion from 11084'to 12013'. Torque connections to 2500 FT/LBS. Install Cannon clamps every connection.Test Tech wire every 30 joints. 04:00 05:30 1.50 12,013 12,013 COMPZ RPCOM HOSO P RIH hole locate top of liner at 12013' with joints 77, 78, 79, 80 to tag NO-GO at 12031' and LD same joints. PU and make up 6.13'pup to space out. Change out elevators to 4.5", MU 3.5"x4.5"XO, pull PS-21 slips and go to hand slips. 05:30 07:00 1.50 12,013 12,013 COMPZ RPCOM THGR P MU 4.5"joint with tubing hanger, terminate I-Wire and test to 5000 psi; Good. Total clamps; 383-3.5"Full clamps, 12- 1/2 clamps, 1-4.5" 1/2 clamp, 1-3.5"x 45". 07:00 07:15 0.25 12,013 12,013 COMPZ RPCOM SFTY P PJSM for pumping corrosion inhibitor with crew. 07:15 09:30 2.25 12,013 12,013 COMPZ RPCOM CRIH P Pump 75 BBL Concor 303 corrosion inhibited 10.0 PPG brine at 3 BPM with360 psi. Chase with 80 BBL 10.0 brine. Drain BOP stack. 09:30 10:00 0.50 12,013 12,013 COMPZ RPCOM THGR P Land tubing hanger and RILDS. 10:00 10:30 0.50 12,013 12,013 COMPZ RPCOM THGR P PT hanger seals to 5000 psi for 15 minutes; Good,witnessed by CPAI rep L. Martin. 10:30 11:15 0.75 12,013 12,013 COMPZ RPCOM PRTS P Drop ball and rod,witnessed by CPAI rep L. Martin. Let fall to seat. 11:15 12:00 0.75 12,013 12,013 COMPZ RPCOM PRTS P Pressure test tubing to 4000 psi for 30 minutes to chart; Good. Bleed tubing to 2000 psi. Crew change. OAP=340 psi. Page 30 of 32 Time Logs 4111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 12,013 12,013 COMPZ RPCOM PRTS P Holding 2000 psi on tubing pressure up on IA to 3500 psi for 30 minutes to chart; Good. bleed off tubing to shear SOV. Bleed off all pressure and pump 10 BBL to check flow; Good with 3 BPM at 1400 psi on reverse circ. 14:00 15:00 1.00 12,013 0 COMPZ RPCOM RURD P Blow down and rig down circulating gear, pull landing joint and LD. 15:00 15:30 0.50 0 0 COMPZ WHDBO MPSP P Install BPV and test to 1500 psi for 15 minutes; Good. Blow down and RD circulating gear. 15:30 21:30 6.00 0 0 COMPZ WHDBO NUND P ND BOPE; pull and clean PS-21 slip system and flow box, pull trip nipple and ND MPD equipment. ND flow line and prep flow box for sliding, ND 4' riser extension, raise stack and pull riser extension aside, lower stack and pull flow box for move. ND stack from riser and move stack to pedestal. ND and pull riser, riser extension and DSA to rig floor, lower same to beaver slide. 21:30 00:00 2.50 0 0 COMPZ WHDBO NUND P Cameron rep well head, remove tree from adapter flange, lower flange and NU to well head. SIMOPs; clean pits. Crew change. 35/05/2015 Continue well head work. SLB terminate I-Wire outside wellhead and test; 2767 psi, 134.66°F final readings. NU tree, change wing valve orientation,test.Test Tree, 250 psi low, 5000 psi high. Freeze protect well, and finish securing well. RDMO 00:00 02:30 2.50 0 0 COMPZ WHDBO PRTS P Continue to NU Cameron well head adapter flange and test to 5000 psi for 15 minutes'witnessed by CPAI P. Smith. Orientation verified by 2L DSO. Terminate SLB TEC wire and test;2767 psi and 134.66°F readings. 02:30 06:30 4.00 0 0 COMPZ WHDBO NUND P NU 4 1/16"Cameron tree, NU wing valve, ND swab valve and orient 180°, NU swab valve, NU blind flange on wing valve,test tree with diesel 250/ 5000 psi 06:30 09:30 3.00 0 0 COMPZ WHDBO PRTS P Test Tree w/diesel,250 psi low, 5000 psi high, 15 charted test. Drain Tree and pull dart HP BPV. 09:30 11:00 1.50 0 0 COMPZ WHDBO FRZP P R/U to Freeze Protect,test lines to 2000 psi. 11:00 14:00 3.00 0 0 COMPZ WHDBO FRZP P Pump 86 bbls of diesel down the IA, 1.5 BPM at 550 psi. Line up on IA and tubing and allow Freeze Protect to U tube from 12:45 to 1400 hrs. Check pressures, 0 psi on the IA and Tubing. Diesel at 2014'both sides. Page 31 of 32 I Time Logs 1111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:30 1.50 0 0 COMPZ WHDBO MPSP P Open IA and Tubing to injection line and bleed down residual pressure. RD surface lines and hoses ensuring 0 psi on Tubing. Install BPV, secure Tree, and shut in Tubing. Final pressures; Tubing=0 psi, IA= 0 psi, OA=240 psi 15:30 18:00 2.50 0 0 DEMOB MOVE RURD P Nipple up and secure Tree. Scope down derrick and begin RD for move to 2N-312. Rig Released from 2L-316 at 18:00 hrs, 5/5/2015. Page 32 of 32 • • NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-316 Definitive Survey Report 07 May, 2015 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-316 Well Position +N/-S 0.00 usft Northing: 5,927,658.00 usfl Latitude: 70°12'47.899 N +EI-W 0.00 usft Easting: 460,917.20 usfl Longitude: 150°18'54.709 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 114.90 usft Wellbore 2L-316 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 4/1/2015 18.65 80.78 57,541 Design 2L-316 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.81 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.81 0.00 0.00 104.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.40 919.36 2L-316 Srvy#1 GYD-GC-SS(2L-316) GYD-GC-SS Gyrodata gyro single shots 4/14/2015 9:01 949.74 2,446.79 2L-316 Srvy#2 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/14/2015 9:1: 2,489.32 2,566.91 2L-316 Srvy#3 MWD+IFR-AK-CAZ-SC(INC+TREND Inclinometer+known azi trend 4/20/2015 4:5: 2,660.98 12,126.71 2L-316 Srvy#4 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/5/2015 4:42, 12,220.64 14,930.00 2L-316 Srvy#5 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2015 11:1E Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.81 0.00 0.00 39.81 -114.90 0.00 0.00 5,927,658.00 460,917.20 0.00 0.00 UNDEFINED 81.25 0.37 252.18 81.25 -73.46 -0.04 -0.13 5,927,657.96 460,917.07 0.89 -0.11 GYD-GC-SS(1) 143.39 0.91 269.94 143.39 -11.32 -0.10 -0.81 5,927,657.90 460,916.38 0.92 -0.76 GYD-GC-SS(1) 165.31 0.88 277.83 165.30 10.59 -0.08 -1.15 5,927,657.93 460,916.04 0.58 -1.10 GYD-GC-SS(1) 204.28 0.67 281.24 204.27 49.56 0.01 -1.67 5,927,658.02 460,915.52 0.55 -1.62 GYD-GC-SS(1) 262.07 1.21 309.23 262.05 107.34 0.46 -2.48 5,927,658.47 460,914.72 1.20 -2.51 GYD-GC-SS(1) 310.17 2.36 328.20 310.13 155.42 1.62 -3.39 5,927,659.64 460,913.81 2.66 -3.68 GYD-GC-SS(1) 356.00 2.68 330.55 355.91 201.20 3.35 -4.42 5,927,661.38 460,912.80 0.73 -5.10 GYD-GC-SS(1) 449.15 3.85 340.21 448.91 294.20 8.19 -6.55 5,927,666.23 460,910.69 1.38 -8.33 GYD-GC-SS(1) 542.74 4.66 351.13 542.24 387.53 14.91 -8.20 5,927,672.95 460,909.08 1.22 -11.56 GYD-GC-SS(1) 635.64 5.69 357.04 634.76 480.05 23.23 -9.02 5,927,681.28 460,908.30 1.25 -14.37 GYD-GC-SS(1) 730.84 6.92 1.62 729.39 574.68 33.68 -9.10 5,927,691.73 460,908.27 1.39 -16.97 GYD-GC-SS(1) 823.69 8.81 5.31 821.36 666.65 46.35 -8.28 5,927,704.39 460,909.16 2.11 -19.25 GYD-GC-SS(1) 919.36 9.60 5.74 915.80 761.09 61.59 -6.80 5,927,719.62 460,910.71 0.83 -21.50 GYD-GC-SS(1) 5/7/2015 4:14:08PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 949.74 9.53 7.17 945.76 791.05 66.60 -6.24 5,927,724.63 460,911.30 0.82 -22.16 MWD+IFR-AK-CAZ-SC(2) 975.62 9.22 7.22 971.29 816.58 70.78 -5.71 5,927,728.81 460,911.85 1.20 -22.66 MWD+IFR-AK-CAZ-SC(2) 1,073.18 11.45 7.05 1,067.26 912.55 88.15 -3.54 5,927,746.16 460,914.11 2.29 -24.76 MWD+IFR-AK-CAZ-SC(2) 1,168.44 13.82 6.16 1,160.21 1,005.50 108.85 -1.16 5,927,766.85 460,916.60 2.50 -27.46 MWD+IFR-AK-CAZ-SC(2) 1,262.37 14.93 7.67 1,251.20 1,096.49 132.00 1.66 5,927,789.97 460,919.54 1.25 -30.32 MWD+IFR-AK-CAZ-SC(2) 1,356.60 16.06 9.98 1,342.00 1,187.29 156.86 5.54 5,927,814.82 460,923.55 1.37 -32.57 MWD+IFR-AK-CAZ-SC(2) 1,451.64 17.26 12.40 1,433.05 1,278.34 183.58 10.85 5,927,841.51 460,928.99 1.46 -33.89 MWD+IFR-AK-CAZ-SC(2) 1,546.19 19.18 17.08 1,522.86 1,368.15 212.13 18.42 5,927,870.02 460,936.71 2.55 -33.44 MWD+IFR-AK-CAZ-SC(2) 1,640.48 20.82 22.38 1,611.47 1,456.76 242.44 29.35 5,927,900.26 460,947.80 2.59 -30.17 MWD+IFR-AK-CAZ-SC(2) 1,736.51 21.25 27.75 1,701.11 1,546.40 273.62 43.96 5,927,931.37 460,962.56 2.06 -23.55 MWD+IFR-AK-CAZ-SC(2) 1,831.04 22.16 38.74 1,788.97 1,634.26 302.70 63.10 5,927,960.34 460,981.85 4.40 -12.01 MWD+IFR-AK-CAZ-SC(2) 1,925.09 22.61 49.44 1,875.97 1,721.26 328.30 87.94 5,927,985.81 461,006.83 4.35 5.91 MWD+IFR-AK-CAZ-SC(2) 2,021.02 23.03 58.24 1,964.42 1,809.71 350.18 117.92 5,928,007.53 461,036.91 3.58 29.70 MWD+IFR-AK-CAZ-SC(2) 2,115.13 24.07 68.17 2,050.72 1,896.01 367.01 151.40 5,928,024.19 461,070.48 4.35 58.11 MWD+IFR-AK-CAZ-SC(2) 2,209.67 25.95 78.42 2,136.43 1,981.72 378.34 189.58 5,928,035.32 461,108.71 4.99 92.42 MWD+IFR-AK-CAZ-SC(2) 2,304.44 25.96 83.60 2,221.66 2,066.95 384.81 230.51 5,928,041.58 461,149.67 2.39 130.57 MWD+IFR-AK-CAZ-SC(2) 2,398.42 28.78 87.30 2,305.11 2,150.40 388.17 273.56 5,928,044.72 461,192.74 3.50 171.53 MWD+IFR-AK-CAZ-SC(2) 2,446.79 31.81 88.65 2,346.87 2,192.16 389.02 297.94 5,928,045.44 461,217.12 6.42 194.98 MWD+I FR-AK-CAZ-SC(2) 2,489.32 32.30 88.65 2,382.92 2,228.21 389.55 320.51 5,928,045.85 461,239.69 1.15 216.75 INC+TREND(3) 2,518.00 32.58 88.78 2,407.12 2,252.41 389.90 335.89 5,928,046.12 461,255.07 1.01 231.59 INC+TREND(3) 103/4"x 13-1/2 2,566.91 33.06 89.00 2,448.23 2,293.52 390.41 362.39 5,928,046.50 461,281.57 1.01 257.18 INC+TREND(3) 2,660.98 35.27 85.95 2,526.06 2,371.35 392.78 415.15 5,928,048.59 461,334.33 2.97 307.80 MWD+IFR-AK-CAZ-SC(4) 2,755.55 37.66 84.54 2,602.12 2,447.41 397.46 471.15 5,928,052.98 461,390.35 2.68 361.01 MWD+IFR-AK-CAZ-SC(4) 2,850.56 40.21 85.14 2,676.01 2,521.30 402.82 530.62 5,928,058.03 461,449.84 2.71 417.40 MWD+IFR-AK-CAZ-SC(4) 2,945.42 44.41 90.07 2,746.17 2,591.46 405.37 594.36 5,928,060.25 461,513.59 5.64 478.64 MWD+IFR-AK-CAZ-SC(4) 3,040.52 49.34 91.81 2,811.16 2,656.45 404.19 663.74 5,928,058.71 461,582.95 5.35 546.24 MWD+IFR-AK-CAZ-SC(4) 3,134.59 53.46 93.69 2,869.84 2,715.13 400.63 737.15 5,928,054.77 461,656.33 4.65 618.33 MWD+IFR-AK-CAZ-SC(4) 3,229.81 56.31 95.87 2,924.61 2,769.90 394.12 814.75 5,928,047.86 461,733.89 3.53 695.20 MWD+IFR-AK-CAZ-SC(4) 3,324.34 58.62 95.82 2,975.45 2,820.74 386.00 894.02 5,928,039.33 461,813.12 2.44 774.08 MWD+IFR-AK-CAZ-SC(4) 3,418.58 59.06 95.99 3,024.21 2,869.50 377.70 974.24 5,928,030.62 461,893.28 0.49 853.92 MWD+IFR-AK-CAZ-SC(4) 3,513.61 59.55 98.00 3,072.72 2,918.01 367.75 1,055.34 5,928,020.25 461,974.32 1.89 935.02 MWD+IFR-AK-CAZ-SC(4) 3,608.38 60.35 99.16 3,120.18 2,965.47 355.51 1,136.45 5,928,007.59 462,055.36 1.35 1,016.69 MWD+IFR-AK-CAZ-SC(4) 3,703.06 63.18 100.05 3,164.97 3,010.26 341.58 1,218.68 5,927,993.24 462,137.51 3.10 1,099.85 MWD+IFR-AK-CAZ-SC(4) 3,797.41 66.02 98.97 3,205.43 3,050.72 327.51 1,302.73 5,927,978.74 462,221.48 3.18 1,184.80 MWD+IFR-AK-CAZ-SC(4) 3,891.81 68.53 98.37 3,241.90 3,087.19 314.39 1,388.80 5,927,965.17 462,307.47 2.72 1,271.49 MWD+IFR-AK-CAZ-SC(4) 3,987.83 71.42 97.73 3,274.78 3,120.07 301.77 1,478.12 5,927,952.08 462,396.71 3.07 1,361.21 MWD+IFR-AK-CAZ-SC(4) 4,082.12 74.16 98.10 3,302.67 3,147.96 289.36 1,567.32 5,927,939.22 462,485.84 2.93 1,450.76 MWD+IFR-AK-CAZ-SC(4) 4,176.24 73.87 98.87 3,328.59 3,173.88 276.01 1,656.81 5,927,925.41 462,575.25 0.84 1,540.82 MWD+IFR-AK-CAZ-SC(4) 4,271.64 73.93 99.95 3,355.05 3,200.34 261.03 1,747.23 5,927,909.96 462,665.59 1.09 1,632.19 MWD+IFR-AK-CAZ-SC(4) 4,365.03 73.93 101.50 3,380.90 3,226.19 244.33 1,835.40 5,927,892.80 462,753.66 1.59 1,721.78 MWD+IFR-AK-CAZ-SC(4) 4,460.49 73.90 102.79 3,407.35 3,252.64 225.03 1,925.07 5,927,873.04 462,843.22 1.30 1,813.45 MWD+IFR-AK-CAZ-SC(4) 4,554.08 73.90 102.49 3,433.30 3,278.59 205.35 2,012.81 5,927,852.91 462,930.85 0.31 1,903.34 MWD+IFR-AK-CAZ-SC(4) 4,648.41 73.86 102.63 3,459.50 3,304.79 185.65 2,101.26 5,927,832.75 463,019.19 0.15 1,993.94 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 4:14:08PM Page 3 COMPASS 5000.1 Build 65 110 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,742.83 73.93 102.71 3,485.69 3,330.98 165.75 2,189.77 5,927,812.40 463,107.58 0.11 2,084.63 MWD+IFR-AK-CAZ-SC(4) 4,837.94 73.93 102.50 3,512.01 3,357.30 145.81 2,278.96 5,927,792.00 463,196.66 0.21 2,175.99 MWD+IFR-AK-CAZ-SC(4) 4,932.46 73.84 102.67 3,538.25 3,383.54 126.02 2,367.58 5,927,771.75 463,285.17 0.20 2,266.77 MWD+IFR-AK-CAZ-SC(4) 5,026.70 73.81 100.70 3,564.51 3,409.80 107.69 2,456.21 5,927,752.97 463,373.69 2.01 2,357.20 MWD+IFR-AK-CAZ-SC(4) 5,216.11 73.81 96.99 3,617.33 3,462.62 79.73 2,635.91 5,927,724.08 463,553.23 1.88 2,538.33 MWD+IFR-AK-CAZ-SC(4) 5,310.55 73.84 96.98 3,643.64 3,488.93 68.70 2,725.94 5,927,712.58 463,643.19 0.03 2,628.35 MWD+IFR-AK-CAZ-SC(4) 5,405.55 73.93 97.60 3,670.01 3,515.30 57.11 2,816.47 5,927,700.53 463,733.65 0.63 2,718.99 MWD+IFR-AK-CAZ-SC(4) 5,500.48 73.90 98.78 3,696.31 3,541.60 44.12 2,906.75 5,927,687.07 463,823.85 1.19 2,809.73 MWD+IF R-AK-CAZ-SC(4) 5,595.51 73.99 99.82 3,722.60 3,567.89 29.36 2,996.87 5,927,671.85 463,913.89 1.06 2,900.75 MWD+IFR-AK-CAZ-SC(4) 5,690.08 73.99 101.56 3,748.68 3,593.97 12.50 3,086.19 5,927,654.53 464,003.11 1.77 2,991.50 MWD+IFR-AK-CAZ-SC(4) 5,784.05 74.47 103.73 3,774.22 3,619.51 -7.30 3,174.43 5,927,634.28 464,091.23 2.28 3,081.90 MWD+IFR-AK-CAZ-SC(4) 5,879.61 74.74 105.79 3,799.59 3,644.88 -30.77 3,263.51 5,927,610.35 464,180.18 2.10 3,174.01 MWD+IFR-AK-CAZ-SC(4) 5,969.07 74.29 106.37 3,823.48 3,668.77 -54.65 3,346.35 5,927,586.04 464,262.89 0.80 3,260.17 MWD+IFR-AK-CAZ-SC(4) 6,068.42 74.01 105.68 3,850.61 3,695.90 -81.03 3,438.21 5,927,559.19 464,354.60 0.73 3,355.68 MWD+IFR-AK-CAZ-SC(4) 6,162.52 72.93 106.77 3,877.39 3,722.68 -106.23 3,524.82 5,927,533.54 464,441.08 1.60 3,445.82 MWD+IFR-AK-CAZ-SC(4) 6,256.49 73.12 106.53 3,904.82 3,750.11 -131.98 3,610.93 5,927,507.34 464,527.04 0.32 3,535.60 MWD+IFR-AK-CAZ-SC(4) 6,352.40 73.10 107.04 3,932.69 3,777.98 -158.49 3,698.79 5,927,480.39 464,614.76 0.51 3,627.27 MWD+IFR-AK-CAZ-SC(4) 6,447.45 73.04 107.31 3,960.37 3,805.66 -185.34 3,785.67 5,927,453.09 464,701.48 0.28 3,718.06 MWD+IFR-AK-CAZ-SC(4) 6,541.66 73.00 106.94 3,987.88 3,833.17 -211.87 3,871.78 5,927,426.12 464,787.44 0.38 3,808.03 MWD+IFR-AK-CAZ-SC(4) 6,636.18 73.14 107.05 4,015.40 3,860.69 -238.30 3,958.25 5,927,399.24 464,873.77 0.19 3,898.33 MWD+IFR-AK-CAZ-SC(4) 6,730.84 74.61 106.06 4,041.69 3,886.98 -264.20 4,045.42 5,927,372.89 464,960.79 1.85 3,989.17 MWD+IFR-AK-CAZ-SC(4) 6,825.55 74.53 106.33 4,066.89 3,912.18 -289.67 4,133.09 5,927,346.97 465,048.32 0.29 4,080.40 MWD+IFR-AK-CAZ-SC(4) 6,920.11 74.61 106.13 4,092.05 3,937.34 -315.14 4,220.61 5,927,321.05 465,135.70 0.22 4,171.48 MWD+IFR-AK-CAZ-SC(4) 7,015.32 74.64 107.25 4,117.30 3,962.59 -341.51 4,308.54 5,927,294.23 465,223.49 1.13 4,263.18 MWD+I FR-AK-CAZ-SC(4) 7,110.53 74.59 107.69 4,142.55 3,987.84 -369.07 4,396.11 5,927,266.22 465,310.90 0.45 4,354.81 MWD+IFR-AK-CAZ-SC(4) 7,205.57 74.20 107.48 4,168.12 4,013.41 -396.72 4,483.37 5,927,238.12 465,398.01 0.46 4,446.17 MWD+IFR-AK-CAZ-SC(4) 7,300.00 73.99 107.27 4,194.00 4,039.29 -423.84 4,570.04 5,927,210.55 465,484.53 0.31 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,395.01 74.08 106.40 4,220.13 4,065.42 -450.30 4,657.47 5,927,183.65 465,571.81 0.89 4,628.06 MWD+IFR-AK-CAZ-SC(4) 7,489.62 74.05 105.25 4,246.11 4,091.40 -475.11 4,744.99 5,927,158.39 465,659.20 1.17 4,718.98 MWD+IFR-AK-CAZ-SC(4) 7,583.63 74.05 103.99 4,271.94 4,117.23 -497.92 4,832.45 5,927,135.13 465,746.53 1.29 4,809.37 MWD+IFR-AK-CAZ-SC(4) 7,678.34 74.08 103.79 4,297.94 4,143.23 -519.78 4,920.86 5,927,112.81 465,834.82 0.21 4,900.44 MWD+IF R-AK-CAZ-SC(4) 7,772.93 74.08 105.19 4,323.89 4,169.18 -542.54 5,008.93 5,927,089.60 465,922.75 1.42 4,991.39 MWD+IFR-AK-CAZ-SC(4) 7,867.45 74.11 106.30 4,349.79 4,195.08 -567.21 5,096.42 5,927,064.48 466,010.11 1.13 5,082.25 MWD+IF R-AK-CAZ-SC(4) 7,962.19 74.08 108.75 4,375.76 4,221.05 -594.64 5,183.29 5,927,036.60 466,096.83 2.49 5,173.18 MWD+IFR-AK-CAZ-SC(4) 8,056.39 74.19 109.40 4,401.51 4,246.80 -624.25 5,268.93 5,927,006.55 466,182.30 0.67 5,263.44 MWD+IFR-AK-CAZ-SC(4) 8,150.73 73.61 109.64 4,427.67 4,272.96 -654.54 5,354.36 5,926,975.82 466,267.57 0.66 5,353.66 MWD+IFR-AK-CAZ-SC(4) 8,244.95 73.69 110.01 4,454.20 4,299.49 -685.20 5,439.41 5,926,944.72 466,352.45 0.39 5,443.60 MWD+IFR-AK-CAZ-SC(4) 8,340.09 73.58 109.25 4,481.00 4,326.29 -715.87 5,525.39 5,926,913.62 466,438.26 0.78 5,534.44 MWD+IFR-AK-CAZ-SC(4) 8,434.93 73.58 109.73 4,507.81 4,353.10 -746.22 5,611.15 5,926,882.82 466,523.85 0.49 5,625.00 MWD+IFR-AK-CAZ-SC(4) 8,529.42 73.63 108.51 4,534.49 4,379.78 -775.91 5,696.79 5,926,852.69 466,609.34 1.24 5,715.28 MWD+IFR-AK-CAZ-SC(4) 8,623.95 73.61 108.73 4,561.14 4,406.43 -804.87 5,782.74 5,926,823.29 466,695.12 0.22 5,805.68 MWD+IFR-AK-CAZ-SC(4) 8,718.56 74.15 109.08 4,587.41 4,432.70 -834.32 5,868.73 5,926,793.40 466,780.95 0.67 5,896.24 MWD+IFR-AK-CAZ-SC(4) 8,813.60 74.17 109.08 4,613.35 4,458.64 -864.20 5,955.13 5,926,763.07 466,867.19 0.02 5,987.31 MWD+IFR-AK-CAZ-SC(4) 8,908.18 74.08 107.73 4,639.23 4,484.52 -892.93 6,041.45 5,926,733.90 466,953.35 1.38 6,078.01 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 4:14:08PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,003.06 74.20 107.04 4,665.16 4,510.45 -920.20 6,128.55 5,926,706.19 467,040.30 0.71 6,169.12 MWD+IFR-AK-CAZ-SC(4) 9,097.82 74.12 105.89 4,691.02 4,536.31 -946.03 6,215.97 5,926,679.90 467,127.58 1.17 6,260.20 MWD+IF R-AK-CAZ-SC(4) 9,192.11 74.14 106.72 4,716.81 4,562.10 -971.50 6,303.02 5,926,653.99 467,214.48 0.85 6,350.82 MWD+IFR-AK-CAZ-SC(4) 9,287.37 74.03 107.00 4,742.93 4,588.22 -998.07 6,390.69 5,926,626.97 467,302.01 0.31 6,442.31 MWD+IFR-AK-CAZ-SC(4) 9,381.66 74.17 106.79 4,768.76 4,614.05 -1,024.42 6,477.46 5,926,600.17 467,388.63 0.26 6,532.88 MWD+IFR-AK-CAZ-SC(4) 9,476.49 74.14 106.76 4,794.65 4,639.94 -1,050.75 6,564.80 5,926,573.39 467,475.83 0.04 6,624.00 MWD+IFR-AK-CAZ-SC(4) 9,571.44 74.14 108.21 4,820.60 4,665.89 -1,078.19 6,651.92 5,926,545.50 467,562.79 1.47 6,715.16 MWD+I FR-AK-CAZ-SC(4) 9,666.22 74.08 107.78 4,846.55 4,691.84 -1,106.35 6,738.61 5,926,516.89 467,649.33 0.44 6,806.10 MWD+IFR-AK-CAZ-SC(4) 9,760.66 74.08 108.10 4,872.46 4,717.75 -1,134.33 6,825.02 5,926,488.48 467,735.58 0.33 6,896.70 MWD+IFR-AK-CAZ-SC(4) 9,855.63 74.14 107.42 4,898.46 4,743.75 -1,162.19 6,912.00 5,926,460.17 467,822.41 0.69 6,987.85 MWD+IFR-AK-CAZ-SC(4) 9,949.63 74.02 108.17 4,924.24 4,769.53 -1,189.81 6,998.07 5,926,432.10 467,908.33 0.78 7,078.04 MWD+IFR-AK-CAZ-SC(4) 10,044.46 74.05 107.26 4,950.33 4,795.62 -1,217.56 7,084.92 5,926,403.91 467,995.02 0.92 7,169.02 MWD+IFR-AK-CAZ-SC(4) 10,139.34 74.47 105.93 4,976.06 4,821.35 -1,243.64 7,172.44 5,926,377.38 468,082.39 1.42 7,260.25 MWD+IFR-AK-CAZ-SC(4) 10,233.24 75.06 105.16 5,000.74 4,846.03 -1,267.92 7,259.72 5,926,352.65 468,169.54 1.01 7,350.81 MWD+IFR-AK-CAZ-SC(4) 10,327.81 75.54 106.36 5,024.74 4,870.03 -1,292.76 7,347.76 5,926,327.35 468,257.44 1.33 7,442.24 MWD+IFR-AK-CAZ-SC(4) 10,422.74 77.50 106.27 5,046.87 4,892.16 -1,318.69 7,436.35 5,926,300.97 468,345.89 2.07 7,534.48 MWD+IFR-AK-CAZ-SC(4) 10,516.49 80.09 105.40 5,065.08 4,910.37 -1,343.78 7,524.81 5,926,275.42 468,434.21 2.91 7,626.39 MWD+IFR-AK-CAZ-SC(4) 10,611.75 80.49 104.69 5,081.15 4,926.44 -1,368.15 7,615.49 5,926,250.58 468,524.75 0.85 7,720.26 MWD+I FR-AK-CAZ-SC(4) 10,706.46 80.66 105.36 5,096.66 4,941.95 -1,392.37 7,705.73 5,926,225.90 468,614.86 0.72 7,813.68 MWD+IFR-AK-CAZ-SC(4) 10,801.55 80.06 105.18 5,112.58 4,957.87 -1,417.06 7,796.16 5,926,200.74 468,705.15 0.66 7,907.40 MWD+IFR-AK-CAZ-SC(4) 10,896.53 80.05 106.72 5,128.99 4,974.28 -1,442.77 7,886.11 5,926,174.57 468,794.96 1.60 8,000.90 MWD+IFR-AK-CAZ-SC(4) 10,990.82 79.03 107.30 5,146.10 4,991.39 -1,469.90 7,974.78 5,926,146.99 468,883.47 1.24 8,093.49 MWD+IFR-AK-CAZ-SC(4) 11,084.14 79.05 107.39 5,163.85 5,009.14 -1,497.21 8,062.23 5,926,119.23 468,970.78 0.10 8,184.95 MWD+I FR-AK-CAZ-SC(4) 11,179.03 79.05 107.82 5,181.87 5,027.16 -1,525.39 8,151.03 5,926,090.60 469,059.42 0.44 8,277.93 MWD+I FR-AK-CAZ-SC(4) 11,274.58 79.13 108.75 5,199.96 5,045.25 -1,554.82 8,240.11 5,926,060.70 469,148.34 0.96 8,371.49 MWD+IFR-AK-CAZ-SC(4) 11,369.07 79.10 108.92 5,217.80 5,063.09 -1,584.78 8,327.93 5,926,030.30 469,236.00 0.18 8,463.95 MWD+IFR-AK-CAZ-SC(4) 11,463.44 79.10 109.08 5,235.64 5,080.93 -1,614.95 8,415.55 5,925,999.68 469,323.45 0.17 8,556.27 MWD+IFR-AK-CAZ-SC(4) 11,557.78 79.19 108.17 5,253.41 5,098.70 -1,644.54 8,503.35 5,925,969.63 469,411.09 0.95 8,648.62 MWD+I FR-AK-CAZ-SC(4) 11,652.59 79.64 108.50 5,270.83 5,116.12 -1,673.86 8,591.82 5,925,939.86 469,499.39 0.59 8,741.55 MWD+IFR-AK-CAZ-SC(4) 11,748.14 79.57 108.75 5,288.07 5,133.36 -1,703.87 8,680.88 5,925,909.39 469,588.28 0.27 8,835.22 MWD+IFR-AK-CAZ-SC(4) 11,842.29 79.51 108.70 5,305.16 5,150.45 -1,733.59 8,768.56 5,925,879.22 469,675.80 0.08 8,927.49 MWD+IFR-AK-CAZ-SC(4) 11,936.81 79.57 110.94 5,322.32 5,167.61 -1,765.11 8,856.00 5,925,847.25 469,763.07 2.33 9,019.96 MWD+IFR-AK-CAZ-SC(4) 12,031.50 79.74 112.93 5,339.33 5,184.62 -1,799.90 8,942.40 5,925,812.02 469,849.28 2.08 9,112.21 MWD+IFR-AK-CAZ-SC(4) 12,126.71 79.98 115.56 5,356.09 5,201.38 -1,838.39 9,027.85 5,925,773.09 469,934.52 2.73 9,204.43 MWD+IFR-AK-CAZ-SC(4) 12,187.00 80.08 118.18 5,366.53 5.211.82 -1,865.22 9,080.81 5,925,745.99 469,987.34 4.28 9,262.31 MWD+IFR-AK-CAZ-SC(5) 7-5/8"x 9-7/8" 12,220.64 80.14 119.64 5,372.31 5,217.60 -1,881.24 9,109.82 5,925,729.82 470,016.26 4.28 9,294.33 MWD+IFR-AK-CAZ-SC(5) 12,270.43 81.20 122.55 5,380.39 5,225.68 -1,906.61 9,151.89 5,925,704.23 470,058.19 6.15 9,341.29 MWD+I FR-AK-CAZ-SC(5) 12,315.32 81.82 125.70 5,387.02 5,232.31 -1,931.52 9,188.64 5,925,679.14 470,094.81 7.08 9,382.97 MWD+IF R-AK-CAZ-SC(5) 12,368.00 81.76 129.46 5,394.54 5,239.83 -1,963.31 9,229.95 5,925,647.14 470,135.95 7.07 9,430.75 MWD+IFR-AK-CAZ-SC(5) 12,410.45 81.82 132.75 5,400.61 5,245.90 -1,990.93 9,261.60 5,925,619.36 470,167.46 7.67 9,468.14 MWD+IFR-AK-CAZ-SC(5) 12,462.71 81.75 136.63 5,408.08 5,253.37 -2,027.30 9,298.37 5,925,582.80 470,204.03 7.35 9,512.61 MWD+I FR-AK-CAZ-SC(5) 12,505.42 81.75 138.34 5,414.20 5,259.49 -2,058.45 9,326.93 5,925,551.50 470,232.43 3.96 9,547.87 MWD+IFR-AK-CAZ-SC(5) , 12,561.12 81.89 139.57 5,422.13 5,267.42 -2,100.03 9,363.13 5,925,509.74 470,268.41 2.20 9,593.05 MWD+IFR-AK-CAZ-SC(5) 5/7/2015 4:14:08PM Page 5 COMPASS 5000.1 Build 65 ® Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,600.04 82.20 140.77 5,427.52 5,272.81 -2,129.63 9,387.82 5,925,480.02 470,292.95 3.16 9,624.17 MWD+IFR-AK-CAZ-SC(5) 12,695.01 83.59 144.09 5,439.27 5,284.56 -2,204.32 9,445.27 5,925,405.04 470,350.00 3.77 9,697.98 MWD+IFR-AK-CAZ-SC(5) 12,789.71 84.38 147.85 5,449.19 5,294.48 -2,282.36 9,497.96 5,925,326.74 470,402.28 4.04 9,767.98 MWD+IFR-AK-CAZ-SC(5) 12,884.18 84.68 150.81 5,458.20 5,303.49 -2,363.23 9,545.93 5,925,245.62 470,449.82 3.14 9,834.09 MWD+IFR-AK-CAZ-SC(5) 12,979.32 86.07 154.40 5,465.87 5,311.16 -2,447.41 9,589.55 5,925,161.23 470,493.00 4.03 9,896.78 MWD+IFR-AK-CAZ-SC(5) 13,075.10 87.61 157.90 5,471.16 5,316.45 -2,534.87 9,628.21 5,925,073.58 470,531.21 3.99 9,955.45 MWD+IFR-AK-CAZ-SC(5) 13,170.26 85.12 158.58 5,477.19 5,322.48 -2,623.06 9,663.41 5,924,985.22 470,565.95 2.71 10,010.94 MWD+IFR-AK-CAZ-SC(5) 13,265.22 84.54 160.19 5,485.75 5,331.04 -2,711.57 9,696.71 5,924,896.54 470,598.79 1.80 10,064.67 MWD+IFR-AK-CAZ-SC(5) 13,359.96 84.99 161.86 5,494.39 5,339.68 -2,800.79 9,727.38 5,924,807.18 470,629.00 1.82 10,116.01 MWD+I FR-AK-CAZ-SC(5) 13,454.46 86.46 164.80 5,501.44 5,346.73 -2,891.05 9,754.41 5,924,716.78 470,655.55 3.47 10,164.07 MWD+I FR-AK-CAZ-SC(5) 13,549.07 86.81 164.19 5,506.99 5,352.28 -2,982.06 9,779.66 5,924,625.65 470,680.33 0.74 10,210.59 MWD+IFR-AK-CAZ-SC(5) 13,644.37 88.20 162.78 5,511.14 5,356.43 -3,073.34 9,806.72 5,924,534.25 470,706.92 2.08 10,258.93 MWD+I FR-AK-CAZ-SC(5) 13,739.33 88.68 160.44 5,513.72 5,359.01 -3,163.41 9,836.67 5,924,444.03 470,736.39 2.51 10,309.78 MWD+IFR-AK-CAZ-SC(5) 13,833.72 88.56 158.34 5,516.00 5,361.29 -3,251.73 9,869.88 5,924,355.55 470,769.15 2.23 10,363.37 MWD+I FR-AK-CAZ-SC(5) 13,928.88 89.57 157.40 5,517.55 5,362.84 -3,339.86 9,905.73 5,924,267.24 470,804.53 1.45 10,419.47 MWD+I FR-AK-CAZ-SC(5) 14,023.98 91.07 152.03 5,517.02 5,362.31 -3,425.82 9,946.33 5,924,181.08 470,844.68 5.86 10,479.66 MWD+IFR-AK-CAZ-SC(5) 14,118.00 90.87 152.78 5,515.43 5,360.72 -3,509.13 9,989.87 5,924,097.56 470,887.79 0.83 10,542.07 MWD+I FR-AK-CAZ-SC(5) 14,212.79 90.60 156.23 5,514.21 5,359.50 -3,594.67 10,030.66 5,924,011.82 470,928.13 3.65 10,602.34 MWD+IFR-AK-CAZ-SC(5) 14,307.10 90.49 156.57 5,513.31 5,358.60 -3,681.09 10,068.42 5,923,925.21 470,965.44 0.38 10,659.88 MWD+IFR-AK-CAZ-SC(5) 14,402.56 89.52 157.16 5,513.31 5,358.60 -3,768.87 10,105.92 5,923,837.25 471,002.48 1.19 10,717.51 MWD+IFR-AK-CAZ-SC(5) 14,497.09 89.60 160.81 5,514.03 5,359.32 -3,857.10 10,139.82 5,923,748.85 471,035.92 3.86 10,771.74 MWD+IFR-AK-CAZ-SC(5) 14,592.25 89.05 162.79 5,515.15 5,360.44 -3,947.48 10,169.54 5,923,658.32 471,065.16 2.16 10,822.44 MWD+IFR-AK-CAZ-SC(5) 14,686.70 89.19 162.31 5,516.60 5,361.89 -4,037.58 10,197.85 5,923,568.09 471,093.01 0.53 10,871.71 MWD+IFR-AK-CAZ-SC(5) 14,781.82 89.43 160.62 5,517.75 5,363.04 -4,127.75 10,228.09 5,923,477.77 471,122.78 1.79 10,922.86 MWD+I FR-AK-CAZ-SC(5) 14,876.92 89.16 157.40 5,518.92 5,364.21 -4,216.52 10,262.15 5,923,388.83 471,156.37 3.40 10,977.39 MWD+IFR-AK-CAZ-SC(5) 14,930.00 88.53 156.63 5,519.99 5,365.28 -4,265.38 10,282.87 5,923,339.88 471,176.84 1.87 11,009.31 MWD+IFR-AK-CAZ-SC(5) 14,990.00 88.53 156.63 5,521.53 5,366.82 -4,320.44 10,306.66 5,923,284.70 471,200.34 0.00 11,045.72 PROJECTED to TD 4 1/2"x 6-3/4" 5/7/2015 4.14.O8PM Page 6 COMPASS 5000.1 Build 65 • • Og Cement Detail Report 2L-316 �illiips u b String: Conductor Job: DRILLING ORIGINAL,4/9/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor 2L-316 Comment No cement required. 16"HW(1.031 WT)was driven to 115 by Peak on 10-27-14. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/20/2015 0 OglC Cement Detail Report 0 2L-316 ConocoPtiilhp5 hm String: Surface Job: DRILLING ORIGINAL,4/9/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface 4/15/2015 04:00 4/15/2015 07:30 2L-316 Comment Dowell Pump 5 bbls of water to fill lines. Pressure test to 3500 psi-ok.Dowell batch up and pump 103 bbls of 10.6 ppg mudPush w/2 gal of red dye @ avg 6 bpm w/final pressure of 188 psi. Dropped bottom plug.Mix lead cement(ALC)@ 11.0 pppg pumped 399 bbls @ 6.8 bbls/min-final pressure 494 psi(observed MudPush to surfce w/290 bbls fo lead slurry pumped)Mixed tail cemen(DeepCrete)@ 12.0 ppg-pumped 63 bbls.@ 5 bbls/min. Final pressure 350 psi- Dropped top plug-Pumped 10 bbls water f/Dowell-Switched over to rig pumps and displaced cmt.w/229 bbls- 10.0 ppg Drillplex mud @ 8 bbls/min-slowed to 3 bbls/min for last 50 bbls of displacement final pressure 225 psi-Didn't bump plug-Full returns during job w/233 bbls 11.0 ppg cmt to surface-Recip. pipe until dropping top plug-loosing down wt.-CIP @ 0700 hrs.-Bled off pressure to check floats-Floats held Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface cement surface pipe 39.0 2,518.0 Yes 233.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 3 7 250.0 0.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,384.0 Drill Bit 2,518.5 9 7/8 Comment Dowell Pump 5 bbls of water to fill lines. Pressure test to 3500 psi-ok. Dowell batch up and pump 103 bbls of 10.6 ppg mudPush w/2 gal of red dye @ avg 6 bpm w/final pressure of 188 psi. Dropped bottom plug. Mix lead cement(ALC)@ 11.0 pppg pumped 399 bbls @ 6.8 bbls/min-final pressure 494 psi(observed MudPush to surfce w/290 bbls fo lead slurry pumped)Mixed tail cemen(DeepCrete)@ 12.0 ppg-pumped 63 bbls.@ 5 bbls/min. Final pressure 350 psi- Dropped top plug-Pumped 10 bbls water f/Dowell-Switched over to rig pumps and displaced cmt.w/229 bbls- 10.0 ppg Drillplex mud @ 8 bbls/min-slowed to 3 bbls/min for last 50 bbls of displacement final pressure 225 psi-Didn't bump plug-Full returns during job w/233 bbls 11.0 ppg cmt to surface-Recip.pipe until dropping top plug-loosing down wt.-CIP @ 0700 hrs.-Bled off pressure to check floats-Floats held Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MPII 100.0 Yield(ft'/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.60 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead 39.0 2,018.0 1,160 ALC 399.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.17 11.00 Additives Additive Type Concentration Conc Unit label Dispersant D145A Additive Type Concentration Conc Unit label Salt D044 %BWOW Additive Type Concentration Conc Unit label Antifoam DO-46 %BWOB Additive Type Concentration Conc Unit label Dispersant D065 %BWOB Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail 2,018.0 2,518.0 220 Deep Crete 63.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 5.46 12.00 Additives Additive Type Concentration Conc Unit label Dispersant D185 Additive Type Concentration Conc Unit label Acelerator D186 Additive Type Concentration Conc Unit label Antifoam D046 %BWOB Page 1/1 Report Printed: 5/20/2015 0 • Cement Detail Report Ot1, 2L-316 Conoc�f'trMips "r.v.`. String: Intermediate Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 4/25/2015 02:00 4/25/2015 05:35 2L-316 Comment Dowell Pump 5 bbls of CW100 to fill lines. Pressure test to 4000 psi-ok. Followed by 45 bbls of CW100 @ 5.5 bpm with 600 psi,followed by 53 bbls of Mud Push II @ 5 bpm with 600 ps. Shut down bleed off and drop bottom plug followed by 252 bbls of GASBLOK 15.8 ppg cement 6 bpm with 600 psi.Shut down and bleed off and drop top plug followed with 10 bbls of water at 6 bpm with 190 psi.Swap over to rig and displace cement with 545 bbls of 9.8+LSND mud at 6 bpm ICP= 150 psi while reciprcating pipe FCP= 1300 psi, started to lose down weight at 3500 stks into displacement, landed hanger on seat and reduced rate to 3 bpm at 5300 stks into displacement ICP=960 psi, FCP=1117 psi, bumped plug at 5413 stks, increase pressure to 1500 psi for 5 min, bleed off pressure and checked floats-Good.-CIP @ 0540 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Cement to Isolate C-37 7,500.0 12,197.0 No Yes Yes Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 0 0 0 0.0 0.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Bump plug at calcuated stks @ 5413 stks. Held 1500 psi for 5 min and bled off and checked floats-Good. (Calcuated TOC is 7500'MD). Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 7,500.0 12,197.0 1,258 G 0.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.25 15.80 51.8 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 Additive Type Concentration Conc Unit label Dispersant D065 Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 Additive Type Concentration Conc Unit label Gas Block D600G Page 1/1 Report Printed: 5/20/2015 i I 215006 25 86 7 ✓ RECEIV ConocoPhillips MAY 2 8 2015 DATA LOGGED TRANSMITTAL AOGCC2.'"15 M.K.BENDER FROM; Sandra D. Lemke,ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave.,Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2L-316 DATE:05/19/2015 Tr.nsmitted: ilKuparuk River Unit, Alaska 2L-316 1 hardcopy report with digital data on CD Halliburton Surface logging data/End of well report;table of contents: General information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey report. Formation Evaluation log -2"MD Gas ratio -2"MD Engineering Log-2"MD fl H CD contains digital data of Final Log files/Final End of Well report/Final LAS exports/Halliburton Log Viewer/EMF Log Viewer Please promptly sign, scan and return electronically to Sandra.D.Lemke000P.com CC: 2L-316 transmittal folder, production well files, eSearch Receipt: / �*x.FF1.a�1-r�., 4-ab : :. -: - 41, GIS-Technical Data Management I ConocoPhillips !Anchorage,Alaska I Ph:90Z265.6947 OF T4 11, �� f/7.' �� THE STATE Alaska Oil and Gas �w�\\ � of f Conservation Commission F �9 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®k. ' 4LASY' Fax: 907.276.7542 www.aogcc.alaska.gov Baskoro Tejo in C Completion Engineer 5 ConocoPhillips Alaska, Inc. p� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-316 Sundry Number: 315-293 Dear Mr. Tejo: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6714--t-7(& Cathy P oerster Chair DATED this day of May, 2015 Encl. , ji�ECIVE® STATE OF ALASKA AKA KA OIL AND GAS CONSERVATION COM . 'ION MAY 13 2015 APPLICATION FOR SUNDRY APPROVALS 1-3-1-3-4-5, s! ti.1-IIS 20 AAC 25.280 AOGGC 1.Type of Request: Abandon I Rug for Redrill f— Perforate New Pool r Repair w ell r Change Approved Program f, Suspend 1--- Rug Perforations [ Perforate r Pull Tubing r Time Extension F Operational Shutdown ;"` Re-enter Susp.Well jjr Stimulate 7`. Alter casing Other:Frac Treatment - 14 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development (. 215-006-0 • 3.Address: Stratigraphic ( Service ( 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20704-00 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 41.50A. Will planned perforations require spacing exception? Yes fl No ( KRU 2L-316 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 380052,380051 . Kuparuk River Field/Tarn Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 14990 5521 , none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 2479 10.75 2518' 2406' INTERMEDIATE 12151 7.625 12188' 5368' LINER 2962 4.5 14990' 5521' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): not perfed yet not perfed yet not available na not available Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Surrrnary of Proposal j 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch E Exploratory r_ Stratigraphic I Development . Service I— 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/28/2015 Oil 5 i ' Gas r WDSPL I— Suspended 16.Verbal Approval: Date: WINJ f— GINJ r WAG I— Abandoned f"` Commission Representative: GSTOR r SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Baskoro Tejo @ 263-4724 Email: Baskaro.Tejo@conocophillips.com Printed Name Baskoro Tejo ` Title: Completion Engineer Signature CsnV.(1. _ / Phone:263-4724 Date 5l i 2 12c,r- Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315 — 2c(S Plug Integrity E BOP Testr Mechanical IntegrityTestr Location Clearance r Other: o 14o'�y`0±t�s C-N.9,CJ r (LQ ILgFrac o< CA est1.Coi 00,,p c sch"c Qtsilm 4„,„(A,...,(,..„ . O C T .L...,S.vf-, rt.s o1-&j repItC of 2,0 4AC .25. 282 Spacing Exception Required? Yes ❑ No +d Subsequent Form Required: /0—40 f APPROVED BY Ap roved by: 9COMMISSIONER THE COMMISSION Date:S—27- 5 _ j(� �Iy Approved application is valid for 12 months'from the dateof approval. Form 10-403(Revised 10/2012L 511/Pc oRIGINAL Submit Form and Attachments in Duplicate /1V2,0/� RBDM MAY 2 8 1015 • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners an operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO TH•LASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2L-316 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283(1)CPAI prepared the attached Notice of Operations("Notice"). 4. On or about May 11th, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 11th day of May,2015. .� L 4/2 Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 11th day of May, 2015, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: r w, STATE OF ALASKA ,,!:,,:\r> NOTARY PUBLIC e. REBECCA SWENSEN My Commission Expires Aug.27,2016 ► • i vry ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com Date: May 11, 2015 To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2L-316 Kuparuk River Unit, Alaska Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2L-316 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about May 11, 2015. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 380052, KRU Tract 130, and ADL 380051, KRU Tract 131 as depicted on Exhibit 1 and as follows: Surface Location: 187.9' FNL, 733.7' FEL, Section 22, T1ON, RO7E, UM Target Location: 1993.1' FNL, 2353.9' FEL, Section 24, T1ON, RO7E, UM Bottomhole Location: 4515.4'FNL, 993.5' FEL, Section 24, T1ON, RO7E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Baskoro Tejo • 2L-316 Hydraulic Fracturing Notice Letter May 11, 2015 Page 2 Exhibit 1 I.AKAI.V L, (.AKAI.V L, t;PAt n TP, TP, 5 [74] BPXA, r• am on~dliffiliNOMIK te—a MIIkl0gAINIO1SMin-a-m ma-mm m——t: MEP MEP EXXON MOBIL 6/30/2012 0/2012 3/27/1984 CL 1 1 IA mile radius from �" 2L-316 Well • • ruk � River ADL380052 ADL380051 ADL025603 CPAI, CPAI, CPAI, BPXA, BPXA, BPXA, CHEVRON, CHEVRON, CHEVRON, EXXON MOBIL EXXON MOBIL EXXON MOBIL 1/31/2003 1 -1(3112003 3/27/1984 130] ® 2(,316 90 23 24 T1ONR7E T1 INR8E ....0) r 1 [134 [95J ADL380054 ADL380053 CPAI, ADI 18 CPA BPXA, CPAI, CPAI BPXA, BPXA CHEVRON, CHEVRON, CHEVRON, EXXON MOBIL EXXON MOBIL 1/31/2003 1/31/2003 EXXON MOBIL 3/27/1984 133 3,6 Legend —Subject Well Q 1/2 Mile Radius ADL375074 LJ Statewide_Oil_and_Gas_Unit_Tracts CPAI, LEASE OPERATOR BPXA, ADL390982 i I BRPC CHEVRON, BPXA Q CPAI iX30N M0 01 136 [165 .IT9NR7E }CHEVRON, I Q REPSOL REFERENCES: EXXON MOBIL Well Data:ConocoPhillips Slolaska Wells y 7/25/12 Published ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Water Well Data:DNR-Groundwater vision Alaska,Inc.Di >No Potable Water Wells are in the Kuparuk River Unit. N 2L-316 Well >No Potable Water Aquifers are in the Kuparuk River Unit n 1 as 0 N Miles 2L316Frac W elleasesI nud CSR 5/62015 2L-316 Hydraulic Fracturing Notice Letter May 11, 2015 Page 3 Exhibit 2 Mineral Owners: Kuparuk River Unit Lands Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director • • Section 2 — Plat 20 AAC 25.283 (a)(2) Southern Miluveach Unit I 2.419 312 ��< �� • i4\ ,A�� \. r y4• 21:=3D7 -01 $710 "'2L-3os T%. �"ea Kuparuk River Unit Tarn PA Legend Wklls Within Radius Subject Well Open Section -',Open Section 112 mile radius 1/2 Mile Radius Participating Area —i Tarn PA CPAI Operated Units ED Other Operated Units REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB ConocoPhi I lips Surface Facilities:North Slope 6K Survey 7/25:12 Published 3/20113 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-316 Plat Anaysis >No Potable Water Aquifers are in the Kuparuk River Unit Wells 5/6/2015 05 • • Drill Well Name API PA Unit Site Status Well Type 2L-03 501032039800 KRU KUP 2L OPSH PROD 2L-301 501032058800 TARNDB KUP 2L ACTIVE INJ 2L-304 501032061300 TARNDB KUP 2L ACTIVE PROD 2L-305 501032027900 TARNDB KUP 2L ACTIVE INJ 2L-306 501032063000 TARNDB KUP 2L ACTIVE PROD 2L-306PB1 501032063070 TARNDB KUP 2L PA EXPEND 2L-307 501032028400 TARNDB KUP 2L ACTIVE PROD 2L-307L1 501032028460 TARNDB KUP 2L ACTIVE PROD 2L-307L2 501032028461 TARNDB KUP 2L ACTIVE PROD 2L-307L2- 01 L-307L2- 01 501032028462 TARNDB KUP 2L ACTIVE PROD 2L-308 501032069400 TARNDB KUP 2L PROP PROD 2L-309 501032052100 TARNDB KUP 2L ACTIVE PROD 2L-309PB1 501032052170 TARNDB KUP 2L PA EXPEND 2L-310 501032061600 TARNDB KUP 2L ACTIVE INJ 2L-311 501032046900 TARNDB KUP 2L ACTIVE PROD 2L-312 501032062600 TARNDB KUP 2L ACTIVE PROD 2L-313 501032027700 TARNDB KUP 2L ACTIVE PROD 2L-314 501032068600 TARNDB KUP 2L ACTIVE PROD 2L-314PB1 501032068670 TARNDB KUP 2L PA EXPEND 2L-315 501032027600 TARNDB KUP 2L ACTIVE PROD 2L-317 501032033600 TARNDB KUP 2L PA PROD 2L-317A 501032033601 TARNDB KUP 2L ACTIVE INJ 2L-318 501032068100 TARNDB KUP 2L ACTIVE INJ 2L-319 501032055200 TARNDB KUP 2L ACTIVE INJ 2L-320 501032062700 TARNDB KUP 2L ACTIVE PROD 2L-320PB1 501032062770 TARNDB KUP 2L PA EXPEND 2L-320PB2 501032062771 TARNDB KUP 2L PA EXPEND 2L-321 501032028600 TARNDB KUP 2L ACTIVE PROD 2L-322 501032062800 TARNDB KUP 2L PA PROD 2L-322A 501032062801 TARNDB KUP 2L ACTIVE PROD 2L-322PB1 501032062870 TARNDB KUP 2L PA EXPEND 2L-323 501032028200 TARNDB KUP 2L ACTIVE INJ 2L-325 501032027500 TARNDB KUP 2L ACTIVE PROD 2L-326 501032059700 TARNDB KUP 2L ACTIVE PROD 2L-327 501032054200 TARNDB KUP 2L ACTIVE PROD 2L-328 501032069800 TARNDB KUP 2L PROP PROD 2L-329 501032027200 TARNDB KUP 2L PA PROD 2L-329A 501032027201 TARNDB KUP 2L ACTIVE INJ 2L-330 501032055400 TARNDB KUP 2L ACTIVE PROD • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exception Title 40 CFR 147.102 (b)(3). Which states "Those portions of aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field" 40 CFR 147.102 - Aquifer exemptions. Updated to July 2013 I Vii. shire in Share *Tweet. Title 40:Protection of Environment CHAPTER I.ENVIRONMENTAL PROTECTION Thanks for the feedback!Back AGENCY(CONTINUED) Welt review this ad to improve your experience in the SUBCHAPTER D:WATER PROGRAMS future. (CONTINUED) Help us show you better ads by updating your ads settings PART 147:STATE,TRIBAL,AND EPA- ADMINISTERED UNDERGROUND INJECTION CONTROL PROGRAMS Subpart C.Alaska 147.102-Aquifer exemptions. (a)This section iden€ifies any aquifers or their portions Go„Sk exempted in accordance with??144.7(b)and 146.4 of this chapter at the time of program promulgation.EPA may in the future exempt other aquifers or portions, according to applicable procedures,without codifying such exemptions in this section An updated list of exemptions will be maintained in the Regional office. (b)The following aquifers are exempted in accordance with the provisions of??144.7(b)and 146.4 of this chapter for Class II injection activities only: (1)The portions of aquifers in the Kenai Peninsula,greater than the indicated depths below the ground surface, and described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields ()Swanson River Feld?1700 feet (ii)Beaver Creek Field21650 feet. (iii)Kenai Gas Field?1300 feet (2)The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields: ()Granite Point (e)McArthur River Field. (iii)Middle Ground Shoal Field. (iv)Trading Bay Field (3)The portions of aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field. • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 2L-316: 10 & 3/4" casing cement pump report on 4/15/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg lead and 12 ppg tail Class G cement, displaced with 10 ppg mud. Full returns were seen for the rest of the job. The plug did not bumped and the floats were checked and they held. 7 & 5/8" casing cement pump report on 4/25/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.8 ppg mud. Full returns were seen throughout the job. The plug bumped @ 960 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 4/16/2015 the10 & 3/4" casing was pressure tested to 3050 psi for 30 mins. On 4/27/2015 the 7 & 5/8" casing was pressure tested to 3000 psi for 30 mins. On 5/4/2015 the 7 & 5/8" casing and production packer were pressure tested to 3500 psi for 30 mins On 5/4/2014 the 3.5" tubing was pressure tested to 3500 psi for 30 mins. • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collaspe 10 3/4" 45.5 L-80 5,210 psi 2,470 psi 7 5/8" 29.7 L-80 6,890 psi 4,790 psi 7 5/8" 39 TN-110 SS 12,620 psi 11,060 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi ! • Stimulation Surface Rig-Up 03 C Bleed t Tattle Tale Tank 00 � 4 i/fit N7 • Minimum pressure rating on all surface treating lines 10,000 psi '1 101 011 r.:81 • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi 00:0 0' • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 g .. _ psi. R? c 064 a E a xorui di und U Pap Olt Tart Pop-0R Tank POI Purr*,Truck ary 2� 41 114.1 1---.J C NIAFrac Pump N y.a7( 1•J Fra_.l-ur112 ,p Fra.Furp N 04 .N r..,J Fra_F unp Frac Pump rv,1 Fr Fur`p • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON /e CONNECTION j D'''' i w i ` f + »„',�. ,. .t MOTE OPERATED i IKIKIIIPmmo MASTER VALVEmoimliwor e �. jot`p ,' MANUAL OPERATED • : ,.$•..kA MASTER VALVE rrirrrr ,.. . • Q r Stinger \ f Stinger \ I. ! MANDREL mi .dr'''' I , , , \ VENT 'LI`)("r-VALVE I . t � I ��V OPEN !� y #1� MIO pis/ — ,I�.:®I 4,kFLOW TEE AND � 1 fiTM` ,�� I ''. u. !_ VENT VALVE WELLHEAD lilt*w,MtV VALVES /rfAum;VA OPEN .t -., :1 :, , . i .4 ,.. �w WELLNEAA n VALVES ,ti+ I ei fii _.D . 'h' OUAO PACKOFF ASSEMBLY fN '.e. j PLACE IN TUBING VP`N $ w4 N itTUNING may' I ,, • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm • 0 Tarn 2L-316 Enterprise(wp46.1) Grass Roots Tooset.Horizontal Multi-Staae Frac'd Producer ConocoPhillips Proposed Wellbore Schematic 'CAMERON Cameron MBS 5K with 4-1/2"hanger/(4-1/16")Tree ' I J � Shultz 71132014 16"62.6#HW @ 106' 3%"Camco DS Nipple 2.875". ' - 13-1/2"Surface Hole 500'MD Drilpiex Mud AA 9.6 PPG 3/"x1"KBMG r Surface Casing: • 10-3/4"45.5#L-80 Hydril 563 - 2,510'MD/2,402'TVD @ 34° 3''/,"x 1"KBMG e Campanian Top 2688'MD(2546'TVD) ND 9-7/8"Intermediate Hole -10.0 PPG 3%"x 1"KBMG 111F Tubing: ep up with 3-W 9.3#L-80 EUE8RD ;,tion 4-1/2"12.6#L-80 IBTM top joint to surface Estimated top of cement +1-7,500'MD (500'above C37) 3'G"x1"KBMG _J Iceberg Top @ C-37 8,037'MD 74.400'rsoi pH Baker CMU Sliding Sleeve CLOSED w/2.812"Camco DS'Profile Liv SLB Downhole Gauge"11,940'MD 3'.5"Camco D Nipple 2.75" :„ 3.5"x 7-5/8",Baker Premier Packer+/-11.966'MD nogo in 7-5/8"x 4-%"Baker Flex Lock Liner hanger ZXP liner top packer wI RS Nipple,@+/-12,011 intermediate Casino Tooset: 7-5/8"29.7#L-80&bottom 300'TN110SS 39#-at Hydril 563 connections 6-1/2"Production Hole 12,187'MD/5,356'ND t 80° . Top of 8ermucta 4 9,." rSwetE Packtirs 12,440 r �5 405 TVD) i. : O O O O O KLASHIELD 9.8-10 PPG .. ... :Prpc lotion IririPT.4 .i..9 Ar Bermuda Pore Pressure :41/2"12 6#I•BTM w/Tq 1i"#tt,S 6.8-8.2-10.7pp9 •' 14 967 i t 5 330 17110, (1,900—2,300 3,000 psi9) ,...10 ::: Base Bermuda 5.XXX'NO14,990'MiJI5, 08'tVD ' • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the fracturing zone, the Bermuda interval, is approximately 212' TVT (955' MD)thick at the heel and approximately 200' TVT at the toe of the well, with the top of the Bermuda starting at 12,240' MD/5,375' TVD. The Bermuda is� mix of laminated shale, siltstone, and sandstone with an estimated fracture pressure of-13.5 ppg. The confining zone of the C-37 to the T-3 is approximately 974' TVT (4,185' MD) thick, with the top of the C-37 starting at 8,054' MD/4,401' TVD. The C-37 to the T-3 is a mix of shale, siltstone, and sandstone lithologies with an estimated fracture pressure as high as -16 ppg.✓ • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2L-301: 7-5/8" casing cement pump report on 1/12/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.6 ppg brine. Full returns were seen throughout the job. The plug bumped @ 1,100 psi and the floats were checked and they held. 2L-304: 7-5/8" casing cement pump report on 4/18/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug bumped @ 1,800 psi and the floats were checked and they held. 2L-309: 7" casing cement pump report on 2/14/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.6 ppg mud. Full returns were seen throughout the job. The plug did not bumped and the floats were checked and they held. 2L-310: 7" casing cement pump report on 5/10/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug bumped @ 1,700 psi and the floats were checked and they held. 2L-311: 3-1/2" x 5-1/2" casing cement pump report on 4/24/2004 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug bumped @ 1,200 psi and the floats were checked and they held. 2L-313: 3-1/2" x 5-1/2" casing cement pump report on 11/20/1998 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug did not bumped and the casing was tested to 3500 psi for 30 min and it held. 2L-317: 7-5/8" casing cement pump report on 5/15/2000 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug did not bumped and the floats were checked and they held. On 12/8/2000, well was plugged back to drill new BHL after logs were evaluated by geologist in town and there was not enough pay-zone present. Bottom plug was pumped with 15.8ppg Class G cement in continuous balance plug. Top KO plug was pumped on 12/10/2000 with 15.8ppg Class G cement. Check for flow, no flow. • • 2L-317A: 3-1/2" x 5-1/2" casing cement pump report on 12/22/2000 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug bumped and the floats were checked and they held. 2L-320: 7-5/8" casing cement pump report on 2/21/2011 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.33 ppg seawater. Full returns were seen throughout the job. The plug bumped @ 1,800 psi and the floats were checked and they held. 2L-320PB1: Due to drilling issue (BHA stuck and well pack off), ECP was set and cement plug pump report on 1/25/2011 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 17ppg Class G cement. Cement was set without any cement returned observed at surface while circulating fluid with the cement stinger assembly in hole. 2L-320PB2: ECP was set and cement plug pump report on 2/3/2011 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 17ppg Class G cement. Cement was set without any cement returned observed at surface while circulating fluid with the cement stinger assembly in hole. r • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there is no known fault or fracture that transects the confining zone within one half mile radius of the wellbore trajectory for 2L-316. • • ADL025590 Souther. Li veach Unit UJ . --- A DL ..ADLI 0052 • ADL380051 2L_376 No Identified Faults Located within Search Radius ADLO 5608 'Tarn Kuparuk River Unit ADL 380054 ADL380053 r� Legend —. Well 1/2 Mile Radius Participating Area ®Tarn PA OCPAI Operated Units ®Other Operated Units REFERENCES: Well Data:ConocoPhillipsAlaska Wells DatabaseATD6 ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil 8 Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-316 Plat Anaysis >No Potable Water Aquifers are in the Kuparuk River UnitA Faults 5/4/2015 1 05 0 M1iiles 2_316F[acwell.mxd CSR 5.612015 • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2L-316 was completed in 2015 as horizontal producer in the Bermuda formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Schlumberger Pumping Services: (Bermuda Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre-existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 22 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 9547 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 152 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 25bpm with a maximum expected treating pressure of 6919 psi. Stage 1 • 400 bbls YF127FIexD Pad • 110 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 130 bbls YF127FIexD w/ 4 ppa 16/20 Carbolite • 140 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 160 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • Drop ball 1 Stage 2 • 400 bbls YF127FIexD Pad • • • 110 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 130 bbls YF127FIexD w/4 ppa 16/20 Carbolite • 140 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 160 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • Drop ball 2 Stage 3 • 450 bbls YF127FIexD Pad • 125 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 125 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 150 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 160 bbls YF127FIexD w/ 4 ppa 16/20 Carbolite • 180 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 200 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • Drop ball 3 Stage 4 • 450 bbls YF127FIexD Pad • 125 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 125 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 150 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 160 bbls YF127FIexD w/4 ppa 16/20 Carbolite • 180 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 200 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • Drop ball 4 Stage 5 • 450 bbls YF127FIexD Pad • 120 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 4 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • 130 bbls YF127FIexD w/ 7 ppa 16/20 Carbolite • 150 bbls YF127FIexD w/ 8 ppa 16/20 Carbolite • Drop ball 5 Stage 6 • 450 bbls YF127FIexD Pad • 120 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 4 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • • • 130 bbls YF127FIexD w/ 7 ppa 16/20 Carbolite • 150 bbls YF127FIexD w/ 8 ppa 16/20 Carbolite • Drop ball 6 Stage 7 • 450 bbls YF127FIexD Pad • 120 bbls YF127FIexD w/ 1 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 2 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 3 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/4 ppa 16/20 Carbolite • 110 bbls YF127FIexD w/ 5 ppa 16/20 Carbolite • 120 bbls YF127FIexD w/ 6 ppa 16/20 Carbolite • 130 bbls YF127FIexD w/ 7 ppa 16/20 Carbolite • 140 bbls YF127FIexD w/ 8 ppa 16/20 Carbolite • Flush with 46 bbls of linear fluid (YF127FIexD) • Flush with 46 bbls of linear fluid (WF127) and 19 bbls freeze protect • Total Sand: Approx. 904,715 lbs 16/20 Carbolite 12. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 410 S ATTACHMENT I:PUMP SCHEDULE Activity ZOOS MAWP 9600 Slurry Rab 20 Hobe.Pump Trip 8800 Proppant Density 2.71 Well Name 2L416 Network number 10370288 Nitrogen PRV 8,000 Annuals Pressure 3500 Hod Type YF127Fbm Proppant Used 16120 CarboLire STEP STAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. PUIP TIME e TYPE RATE RATE STAGE CUM STAGE CUA STAGE CUM SIZE GROSS CUM Breaker STAGE CUM (BPM) (BPM) (DELI (BBL) (GAL) (GAL) (Las) (LBS) (BBL) (BBL) IDM9M1 (hh:mm:ss) (hh:mm:ss) t Injection test WF127 20 20.0 152 152 6384 6384 152 152 8.0 12:07:36 AM 12:07:38 AM Hard shutdown:monitor pressure. 0.0 12:00:00 AM 12:07:38 AM 2 Pad YF127FIexD 20 20,0 80 232 3360 9744 80 232 8.0 12:04:00 AM 12:11:36 AM 3 I Sand YF127FIe00 20 192 50 282 2100 11844 2011 2011 16120 Carts,. 48 280 8.0 12:02:30 AM 12:14:06 AM Spacer YF127FIe05 20 20,0 80 362 3360 15204 80 360 8.0 12:04:00 AM 12:18:06 AM 5 Displacement WF127 20 20.0 152 514 6384 21588 152 512 8.0 12:07:36 AM 12:25:42 AM Hard shutdown;monitor pressure. FLUID PLOW OF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. PUIF TIME STEP STAGE AVERAGE CCONENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker STAGE CUM N M PPA (BPM) (6P55 18BL1 (BBL) (GAL) (GAL) (L85) (LOS) (BBL) (BBL) (811941 (DBL) (BBL) 6 PAD YF727FIexD 20 20.0 400 916 16800 38388 0 2011 0 400 312 8.0 12:20:00 AM 12:45:42 AM 7 1 FLAT YF727FIexD 20 19.2 110 1024 4620 43008 4424 6,435 'arta...up 105 1017 10.0 12:05:30 AM 12:51:12 AM 9 2 FLAT YF727FIexD 20 18.4 110 1134 4620 47628 8489 14924 160002rbolite 101 1118 10.0 12:05:30 AM 12:56:42 AM 9 3 FLAT YF727FIexD 20 17,7 120 1254 5040 52868 13348 28,272 106 1224 10.0 12:06:00 AM 1:02:42 AM 10 4 FLAT YF727FIexD 20 17.0 130 1384 5460 58128 18556 46,828 moo 02rbalr. 110 1335 10.0 12:06:30 AM 1:09:12 AM II 5 FLAT VF127FIex0 20 16.4 140 1524 5880 64008 24074 70,902 moo anSeE a.. 115 1449 10.0 12:07:00 AM 1:18:12 AM 12 6 FLAT YF727FIexD 20 15.8 160 1684 8720 70728 31682 102,764 16900erboLN.- 126 1576 10.0 12:08:00 AM 1:24:12 AM 13 Ball 1.50' DISPLACE YF127FIexD 20 20.0 15 1699 830 713580 102,764 15 1591 8.0 12:00:45 AM 1:24:57 AM 14 PAD YF127FIeoD 20 20.0 400 2099 16800 88158 0 102,764 400 1991 8.0 12:20:00 AM 1:44:57 AM 15 1 FLAT YF127FIex0 20 19.2 110 2209 4620 92778 4424 107,188 1560 Great. 105 2096 10.0 12:05:30 AM 1:50:27 AM 16 2 FLAT YF727FIex0 20 18,4 110 2319 4620 97398 8489 115,877 1830 CarbeSte 101 2197 10.0 12:05:30 AM 1:55:57 AM 17 3 FLAT YF127FIexD 20 17.7 120 2439 5040 102438 13348 129,025 miza 0.1540. 106 2303 10.0 12:08:00 AM 2:01:57 AM 18 4 FLAT YF727FIexD 20 17.0 130 2569 5480 107896 18556 147,581 15G0 Care.. 110 2414 10.0 12:06:30 AM 2:08:27 AM 19 5 FLAT YF727FIexD 20 16.4 140 2709 5880 113778 24074 171,656 1630 arbcAl. 115 2528 10.0 12:07:00 AM 2:15:27 AM 20 6 FLAT YF127FIexD 20 15.9 160 2869 6720 120498 31862 203,517 1039 arboUte 126 2655 10.0 12:08:00 AM 2:23:27 AM 2) Ball 1.625" DISPLACE YF127FIROD 20 20.0 12 2881 504 121002 0 203,517 12 2667 8.0 12:00:38 AM 2:24:03 AM 22 PAD YF927FIexD 20 20.0 450 3331 18900 139902 0 203,517 450 3117 8.0 12:22:30 AM 2:46:33 AM 23 1 FLAT YF127FIexD 20 107 125 3458 5250 145152 5028 208,545 mooarboAb 120 3236 10.0 12:06:15 AM 2:52:48 AM 24 2 FLAT YF127FIexD 20 10.4 125 3581 5250 150402 9646 218,197 moo cared. 115 3351 10.0 12:06:15 AM 2:59:03 AM 25 3 FLAT YF127FIexD 20 17.1 150 3731 6300 156702 16685 234,878 rano 0.13010. 132 3484 10.0 12:07:30 AM 3:06:33 AM 28 4 FLAT YF127FIe0D 20 17.0 160 3891 6720 163422 22838 257,715 1690 0ar500. 136 3620 10.0 12:06:00 AM 3:14:33 AM 27 5 FLAT YF127FIexD 20 10.4 180 4071 7560 170982 30953 288,667 ta0oa,000I. 147 3767 10.0 12:09:00 AM 3:23:33 AM 28 6 FLAT YF127FIexD 20 15.8 200 4271 _ 8400 179382 39827 328,494 le8oaro8ON 158 3925 10.0 12:10:00 AM 3:33:33 AM 29 Bell 1,75" DISPLACE YF727FIezD 20 20.0 12 4283 504 1798860 326,494 12 3937 8.0 12:00:36 AM 3:34:09 AM 30 PAD YF727FIexD 20 20,0 450 4733 18900 1987860 328,494 450 4387 8.0 12:22:30 AM 3:56:39 AM 31 1 FLAT VF127FIe00 20 19.2 125 4858 5250 204036 5028 333,522 120 4507 10.0 12:06:15 AM 4:02:54 AM 32 2 FLAT YF127FIeCD 20 18.4 125 4983 5250 209286 9646 343,168 0arboLOe 115 4621 10.0 12:06:15 AM 4:09:09 AM 33 3 FLAT YF127FIexD 20 17.7 150 5133 6300 215586 18685 359,853 1830arbOLS 132 4754 10.0 12:07:30 AM 4:16:39 AM 34 4 FLAT YF727F1ezD 20 17.0 180 5293 6720 222306 22838 382,692 moo carbouta 136 4890 10.0 12:08:00 AM 4:24:39 AM 35 5 FLAT YF727FIez13 20 13.4 180 5473 7560 229886 30953 413,844 15O0 Carts.. 147 5037 10.0 12:09:00 AM 4:33:39 AM 36 6 FLAT YF727FIezD 20 15.0 200 5673 8400 238286 39827 453,471 1600 Carbouta 158 5195 10.0 12:10:00 AM 4:43:39 AM 37 Ball 1.875" DISPLACE YF727FIezD 25 25 12 5685 504 2387700 453,471 12 5207 8.0 12:00:28 AM 4:44:07 AM 38 PAD YF727FIezD 25 20.0 450 6735 18900 2576700 453,471 450 5657 8.0 12:18:00 AM 5:02:07 AM 39 1 FLAT YF727FIexD 25 27.0 120 8255 5040 262710 4826 458,298 10acarboub. 115 5772 10.0 12:04:48 AM 5:06:55 AM 40 2 FLAT YF127FIex0 25 23.0 120 6375 5040 267750 9261 467,558 1600 corbeLE. 110 5882 10.0 12:04:48 AM 5:11:43 AM 41 3 FLAT YF727FIexD 25 22.1 110 6485 4620 272370 12236 479,794 urn co... 97 5980 10.0 12:04:24 AM 5:16:07 AM 42 4 FLAT YP127FIex13 25 21.2 110 6595 4620 276990 15701 405,495 moo coLuLne93 6073 10.0 12:04:24 AM 5:20:31 AM 43 5 FLAT YF727FIex13 25 20.5 110 6705 4620 281610 18915 514,411 levo..bout. 90 6163 10.0 12:04:24 AM 5:24:55 AM 44 6 FLAT YF727FIexD 25 15.8 120 6825 5040 288650 23896 538,307 1639 carnotite 95 8258 10.0 12:04:48 AM 5:29:43 AM 45 7 FLAT YF727FIe8D 25 19.1 130 6955 5460 292110 29182 567,489 1639 0.05405 99 8357 10.0 12:05:12 AM 5:34:55 AM 46 8 FLAT YF127FIexD 25 19.5 180 7105 6300 298410 37224 604,713 1630 arbeAte 111 6468 10.0 12:06:00 AM 5:40:55 AM 47 04112.00" DISPLACE YF727F1e05 25 25.0 12 7117 504 2989140 604,713 12 6480 8.0 12:00:28 AM 5:41:23 AM 48 PAD YF727FIexD 25 25.0 450 7567 18900 317814 0 604,713 450 6930 8.0 12:18:00 AM 5:59:23 AM 49 1 FLAT YF727FIexD 25 23.0 120 7687 5040 322854 4826 609,539 mita 0.0,49. 115 7045 10.0 12:04:48 AM 6:04:11 AM 50 2 FLAT YF727FIexD 25 23.0 120 7807 5040 327894 9261 618,800 110 7155 10.0 12:04:48 AM 8:08:59 AM 51 3 FLAT YF727FIe0D 25 22.1 110 7917 4620 332514 12236 631,036 l630 arboute 97 7252 10.0 12:04:24 AM 6:13:23 AM 52 4 FLAT YF727FIe0D 25 21.2 110 8027 4620 337134 15701 646,737 1600arSOLm 93 7346 10.0 12:04:24 AM 6:17:47 AM 53 5 FLAT YF727FIezD 25 20.5 110 8137 4620 341754 18915 665,652 1600 Cart.. 90 7436 10.0 12:04:24 AM 6:22:11 AM 54 6 FLAT YF727FIexD 25 15.8 120 8257 5040 346794 23896 689,549 1630 amoub 95 7531 10.0 12:04:48 AM 6:26:59 AM 55 7 FLAT YF727FIexD 25 19.I 130 8387 5460 352254 29182 718,731 16000arbOAl. 99 7630 10.0 12:05:12 AM 6:32:11 AM 56 8 FLAT YF727FIexD 25 18,55 150 8537 6300 358554 37224 755,955 160oarbeAI. 111 7741 10.0 12:08:00 AM 6:38:11 AM 57 7 Ball 2.125" DISPLACE YF727FIexD 25 25 10 8547 420 3589740 755,955 10 7751 8.0 12:00:24 AM 6:38:35 AM 50 7 PAD YF727FIexD 25 20.0 450 8997 18900 377874 0 755,955 450 8201 8.0 12:18:00 AM 6:56:35 AM 59 7 1 FLAT YF727FIexD 25 23.6 120 9117 5040 382914 4826 780,781 woo carom... 115 8316 10.0 12:04:48 AM 7:01:23 AM 80 7 2 FLAT YF727FIexD 25 23.0 120 9237 5040 387954 9261 770,042 1820 amour 110 8426 10.0 12:04:48 AM 7:06:11 AM 61 7 3 FLAT YF727FIexD 25 22,1 110 9347 4620 392574 12236 782,278 woo ameuta 97 8523 10.0 12:04:24 AM 7:10:35 AM 62 7 4 FLAT YF727FIexD 25 21.7 110 9457 4820 397194 15701 797,979 1800 05rne0. 93 8616 10.0 12:04:24 AM 7:14:59 AM 63 7 5 FLAT YF727FIexD 25 20.5 110 9567 4620 401814 18915 818,894 taco arboLE. 90 8706 10.0 12:04:24 AM 7:19:23 AM 64 7 6 FLAT YF727FIexD 25 19.0 120 9687 5040 406854 23896 840,790 w3oaro Lim 95 8801 10.0 12:04:48 AM 7:24:11 AM 65 7 7 FLAT YF727FIexD 25 19,1 130 9817 5460 412314 29182 869,972 N.carbaute 99 8901 10.0 12:05:12 AM 7:29:23 AM 86 7 8 FLAT YF727F1e8D 25 18.5 140 9957 5880 418194 34743 904,715 woo OaroeLOe 103 9004 10.0 12:05:36 AM 7:34:59 AM 87 7 FLUSH YF127FIe80 25 25,0 46 10003 1950 420144 46 9050 10.0 12:01:51 AM 7:36:50 AM ea 7 FLUSH WF127 25 20.0 46 10050 1950 422094 46 9097 10.0 12:01:51 AM 7:38:41 AM 69 7 FLUSH Freezeproteet 25 25.0 19 10069 804 422898 19 9118 12:00:45 AM 7:39:26 AM TOTALS 10069 904715 9116 7:39:28 AM SD and obtain!SIP A 15 min SIP. WATER VOL FLUSH INFORMATION WELL AND TREATING PRESSURE INFORMATION WORLAND FRAC ORIENTATION INFORMATION DMaFRAC= 512 bb's VOL TO TOP PORT=1115.8 ISIP GRADIENT= 0.76 BHP=4196 DIP TVD Ped.H,B= MAIN JOB= 8585bbls Extra 450 595 -UNDERFLUSHS 3.0 FLUID SG= 1,030 ♦TEG FRIG=4173psi TOTAL JOB= 9097 bbls FLUSH VOL=112 FRICnON LOSS• 02799 ♦PERF FRIL=0300 psi 9547 bbls -with contingency _ MD TO Thy Tall= 12055 -HYD HEAD=2466 psi Angle Through Perth= GENERAL JOB INFO TVD BTM SLEEVE= 5621 EST.MAX WHP=6203 psi WA)Azimuth 7810800 TANKS REQUIRED PIPE TIME(min).5.8 MD FIRST SLEEVE= U915 .. iso 21.22 0 450 XI per tank pump.. PAD/SLURRY RATIO Stager 34% Stage6 32% Stage 234% Stage 7 32% TOTALS FOR II STAGES Stage 332% Stage 8 UPPER TUBING SIZE= 3.6000 0.0087 55ivrt Pore.. Stage 4 32% Stage 9 MIDDLE TUBING SIZE= 5550 Water 9547 bbls Stage 5326, Stage 10 LOWER TUBING SIZE= 5550 Reservoir Pressure=3400 Xlink fluid 8793 .talo Stage Porta MD Displacement LENGTH MIDDLE TBG 4 Permeability= Linear fluid 350 bbl. nameR wlume Sat Size LENGTH LOWER TMG• Tanperadta=160 Proppant 904,715 IS Stage 1 14916 148.4 bbl. Pert Sub CASING SIZE= 4.5000 0.0152 .Msec Diesel S7 bbl. Stage 2 14558 142.9 bbls 1.553 J475 3,516 lb Stage 3 14192 137.4 bbls 1.678 1 Pump time 7:39:26 AM hh:mm:a. Stage 4 13868 132.5 bbl. 1.803 Stage 5 13506 126.9 bbls 1.928 J511 1,506 lb Stage6 13142 121A bbls 2.053 L065 710 gal Stage 7 12776 115.8 bbls 2.178 F103 383 gal .1604 923 gal 51002 1,034 Ib 8982 2,412 gal 5,114015 • • Client: ConocoPhillips Alaska Schlumberger Well: 2L-316 Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 5/4/2015 10:32 AM Report ID: RPT-36648 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 2,457.0 Gal F103 Surfactant 1 Gal/1000 Gal 390.0 Gal J218 Breaker 0.1 Lb/1000 Gal 25.0 Lb 1475 Breaker 9.2 Lb/1000 Gal 3,600.0 Lb _ YF1275T,WF127 391,146 Gal J511 Stabilizing Agent 4.9 Lb/1000 Gal 1,920.0 Lb J604 Crosslinker 2.4 Gal/1000 Gal 945.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 780.0 Gal M002 Additive 2.7 Lb/1000 Gal 1,060.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 115.0 Lb S522-1620 Propping Agent varied concentrations 910,000.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* "77 % 66402-68-4 Ceramic materials and wares,chemicals "'22 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 9000-30-0 Guar gum <1 % 107-21-1 Ethylene Glycol <1 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 50-70-4 Sorbitol <0.1 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1 % 1310-73-2 Sodium hydroxide(impurity) <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 111-76-2 2-butoxyethanol <0.1 % 67-63-0 Propan-2-ol <0.1 % 11138-66-2 Gum,xanthan <0.1 % 1330-43-4 Sodium tetraborate <0.01 % 7647-14-5 Sodium chloride <0.01 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) <0.01 % 7631-86-9 Silicon Dioxide <0.01 % 10043-52-4 Calcium Chloride <0.01 % 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 111-46-6 2,2"-oxydiethanol(impurity) <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 68153-30-0 Amine treated smectite clay <0.001 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 14808-60-7 Crystalline silica(impurity) <0.0001 % 14464-46-1 Cristobalite <0.0001 % Total 10u X .Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. 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N .c C U N N L = CJ s , L ca U w N .- N Ct. ° o 3 o u a i5 -a a, M co 1 in TO LS c 0 .� u .- 0 I Na o v J 00 coo , i }? v c ..C; OOA a)) u co Q ; c c -a co • O. V 0 ii c co c° Q '.}>-, . v - o > a, C O L '3 v 'c N N °' v -a 1L o 0 o I 3 i N O N 4- -0 L1 L +J L C G I Q •+-� 4" C N ;ITN M -0 C > Q vQ OO I C .O UA ! hA 1 OO 0. V 4- ccv 3'O ! L c ) v1 ir ' 1N , j ! v ±-o I > j I ; „ I 1 I > Iv I ``• ( 1' C an 1 v -a I , oQ 0 ! � Iasi OA L a)E N '.- C I i a) L ! 3 C L a, E v `° c I = � „. c I a`) M. I = C N = c o U Q o f U d u 'C >-' a LOL i`� OCA (0 CU C t m C O V C U l y •- C i•L 4L.. 0 O V) Q C .- to O Q,V ro U {/) N o Y 1 LL d C O U _-.._.-.--_1_..-_.... __-___.._. _ __.._--_.._._ .-..._. _._- .._...__ ._-.-__ ••••••• . ...__- a • RECEIVED • 21 5 0 0 6 MAY 122015 25909 AOGCC Transmittal#: 12MAY15-SP02 Schlumberger PetroTechnical Services DATA LOGGED Product Delivery b i2/2o1S M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-316 Date Dispatched: 12-May-15 Job#: 14AKA0121 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A PTS Answer Product SonicScope:Top of Cement x x 6,910'to 12,500' LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(c conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 170Mz447) `��`c Received By: dECEIVED • 21 50 06 MAY122015 25810 AOGCC SchlumbergerDrilling & Measurements Transmittal#: 12MAY15-SPO1 DATA LOGGED MWD/LWD Log Product Delivery b/ /2O15 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-316 Date Dispatched: 12-May-15 Job#: 14AKA0121 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 2'TVDSS x x VISION*Service 5'MD - x x VISION*Service 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosoconocophillips.com AlaskaPTSPrintCenter c(7slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 ii9A4,242.4za...7/7)Received By: 6...e.oteat 25810 • • 21 50 06 RECEIVED MAY 12 2015 AOGCC FINAL NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-316 Definitive Survey Report NAD 27 07 May, 2015 r • - Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-316 Well Position +N/-S 0.00 usft Northing: 5,927,658.00 usfl Latitude: 70°12'47.899 N +El-W 0.00 usft Easting: 460,917.20 usfl Longitude: 150°18'54.709 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 114.90 usft Wellbore 2L-316 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 4/1/2015 18.65 80.78 57,541 Design 2L-316 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.81 Vertical Section: Depth From(TVD) +N/-5 +EI-W Direction (usft) (usft) (usft) (°) 39.81 0.00 0.00 104.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.40 919.36 2L-316 Srvy#1 GYD-GC-SS(2L-316) GYD-GC-SS Gyrodata gyro single shots 4/14/2015 9:01 949.74 2,446.79 2L-316 Srvy#2 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/14/2015 9:1: 2,489.32 2,566.91 2L-316 Srvy#3 MWD+IFR-AK-CAZ-SC(INC+TREND Inclinometer+known azi trend 4/20/2015 4:5: 2,660.98 12,126.71 2L-316 Srvy#4 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/5/2015 4:42: 12,220.64 14,930.00 2L-316 Srvy#5 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2015 11:1E Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.81 0.00 0.00 39.81 -114.90 0.00 0.00 5,927,658.00 460,917.20 0.00 0.00 UNDEFINED 81.25 0.37 252.18 81.25 -73.46 -0.04 -0.13 5,927,657.96 460,917.07 0.89 -0.11 GYD-GC-SS(1) 143.39 0.91 269.94 143.39 -11.32 -0.10 -0.81 5,927,657.90 460,916.38 0.92 -0.76 GYD-GC-SS(1) 165.31 0.88 277.83 165.30 10.59 -0.08 -1.15 5,927,657.93 460,916.04 0.58 -1.10 GYD-GC-SS(1) 204.28 0.67 281.24 204.27 49.56 0.01 -1.67 5,927,658.02 460,915.52 0.55 -1.62 GYD-GC-SS(1) 262.07 1.21 309.23 262.05 107.34 0.46 -2.48 5,927,658.47 460,914.72 1.20 -2.51 GYD-GC-SS(1) 310.17 2.36 328.20 310.13 155.42 1.62 -3.39 5,927,659.64 460,913.81 2.66 -3.68 GYD-GC-SS(1) 356.00 2.68 330.55 355.91 201.20 3.35 -4.42 5,927,661.38 460,912.80 0.73 -5.10 GYD-GC-SS(1) 449.15 3.85 340.21 448.91 294.20 8.19 -6.55 5,927,666.23 460,910.69 1.38 -8.33 GYD-GC-SS(1) 542.74 4.66 351.13 542.24 387.53 14.91 -8.20 5,927,672.95 460,909.08 1.22 -11.56 GYD-GC-SS(1) 635.64 5.69 357.04 634.76 480.05 23.23 -9.02 5,927,681.28 460,908.30 1.25 -14.37 GYD-GC-SS(1) 730.84 6.92 1.62 729.39 574.68 33.68 -9.10 5,927,691.73 460,908.27 1.39 -16.97 GYD-GC-SS(1) 823.69 8.81 5.31 821.36 666.65 46.35 -8.28 5,927,704.39 460,909.16 2.11 -19.25 GYD-GC-SS(1) 919.36 9.60 5.74 915.80 761.09 61.59 -6.80 5,927,719.62 460,910.71 0.83 -21.50 GYD-GC-SS(1) 5/7/2015 4:14:08PM Page 2 COMPASS 5000.1 Build 65 • • . Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 949.74 9.53 7.17 945.76 791.05 66.60 -6.24 5,927,724.63 460,911.30 0.82 -22.16 MWD+IFR-AK-CAZ-SC(2) 975.62 9.22 7.22 971.29 816.58 70.78 -5.71 5,927,728.81 460,911.85 1.20 -22.66 MWD+IFR-AK-CAZ-SC(2) 1,073.18 11.45 7.05 1,067.26 912.55 88.15 -3.54 5,927,746.16 460,914.11 2.29 -24.76 MWD+IFR-AK-CAZ-SC(2) 1,168.44 13.82 6.16 1,160.21 1,005.50 108.85 -1.16 5,927,766.85 460,916.60 2.50 -27.46 MWD+IFR-AK-CAZ-SC(2) 1,262.37 14.93 7.67 1,251.20 1,096.49 132.00 1.66 5,927,789.97 460,919.54 1.25 -30.32 MWD+IFR-AK-CAZ-SC(2) 1,356.60 16.06 9.98 1,342.00 1,187.29 156.86 5.54 5,927,814.82 460,923.55 1.37 -32.57 MWD+IFR-AK-CAZ-SC(2) 1,451.64 17.26 12.40 1,433.05 1,278.34 183.58 10.85 5,927,841.51 460,928.99 1.46 -33.89 MWD+IFR-AK-CAZ-SC(2) 1,546.19 19.18 17.08 1,522.86 1,368.15 212.13 18.42 5,927,870.02 460,936.71 2.55 -33.44 MWD+IFR-AK-CAZ-SC(2) 1,640.48 20.82 22.38 1,611.47 1,456.76 242.44 29.35 5,927,900.26 460,947.80 2.59 -30.17 MWD+IFR-AK-CAZ-SC(2) 1,736.51 21.25 27.75 1,701.11 1,546.40 273.62 43.96 5,927,931.37 460,962.56 2.06 -23.55 MWD+IFR-AK-CAZ-SC(2) 1,831.04 22.16 38.74 1,788.97 1,634.26 302.70 63.10 5,927,960.34 460,981.85 4.40 -12.01 MWD+IFR-AK-CAZ-SC(2) 1,925.09 22.61 49.44 1,875.97 1,721.26 328.30 87.94 5,927,985.81 461,006.83 4.35 5.91 MWD+IFR-AK-CAZ-SC(2) 2,021.02 23.03 58.24 1,964.42 1,809.71 350.18 117.92 5,928,007.53 461,036.91 3.58 29.70 MWD+IFR-AK-CAZ-SC(2) 2,115.13 24.07 68.17 2,050.72 1,896.01 367.01 151.40 5,928,024.19 461,070.48 4.35 58.11 MWD+IFR-AK-CAZ-SC(2) 2,209.67 25.95 78.42 2,136.43 1,981.72 378.34 189.58 5,928,035.32 461,108.71 4.99 92.42 MWD+IFR-AK-CAZ-SC(2) 2,304.44 25.96 83.60 2,221.66 2,066.95 384.81 230.51 5,928,041.58 461,149.67 2.39 130.57 MWD+IFR-AK-CAZ-SC(2) 2,398.42 28.78 87.30 2,305.11 2,150.40 388.17 273.56 5,928,044.72 461,192.74 3.50 171.53 MWD+IFR-AK-CAZ-SC(2) 2,446.79 31.81 88.65 2,346.87 2,192.16 389.02 297.94 5,928,045.44 461,217.12 6.42 194.98 MWD+IFR-AK-CAZ-SC(2) 2,489.32 32.30 88.65 2,382.92 2,228.21 389.55 320.51 5,928,045.85 461,239.69 1.15 216.75 INC+TREND(3) 2,518.00 32.58 88.78 2,407.12 2,252.41 389.90 335.89 5,928,046.12 461,255.07 1.01 231.59 INC+TREND(3) 10 3/4"x 13-1/2 2,566.91 33.06 89.00 2,448.23 2,293.52 390.41 362.39 5,928,046.50 461,281.57 1.01 257.18 INC+TREND(3) 2,660.98 35.27 85.95 2,526.06 2,371.35 392.78 415.15 5,928,048.59 461,334.33 2.97 307.80 MWD+IFR-AK-CAZ-SC(4) 2,755.55 37.66 84.54 2,602.12 2,447.41 397.46 471.15 5,928,052.98 461,390.35 2.68 361.01 MWD+IFR-AK-CAZ-SC(4) 2,850.56 40.21 85.14 2,676.01 2,521.30 402.82 530.62 5,928,058.03 461,449.84 2.71 417.40 MWD+IFR-AK-CAZ-SC(4) 2,945.42 44.41 90.07 2,746.17 2,591.46 405.37 594.36 5,928,060.25 461,513.59 5.64 478.64 MWD+IFR-AK-CAZ-SC(4) 3,040.52 49.34 91.81 2,811.16 2,656.45 404.19 663.74 5,928,058.71 461,582.95 5.35 546.24 MWD+IFR-AK-CAZ-SC(4) 3,134.59 53.46 93.69 2,869.84 2,715.13 400.63 737.15 5,928,054.77 461,656.33 4.65 618.33 MWD+IFR-AK-CAZ-SC(4) 3,229.81 56.31 95.87 2,924.61 2,769.90 394.12 814.75 5,928,047.86 461,733.89 3.53 695.20 MWD+IFR-AK-CAZ-SC(4) 3,324.34 58.62 95.82 2,975.45 2,820.74 386.00 894.02 5,928,039.33 461,813.12 2.44 774.08 MWD+IFR-AK-CAZ-SC(4) 3,418.58 59.06 95.99 3,024.21 2,869.50 377.70 974.24 5,928,030.62 461,893.28 0.49 853.92 MWD+IFR-AK-CAZ-SC(4) 3,513.61 59.55 98.00 3,072.72 2,918.01 367.75 1,055.34 5,928,020.25 461,974.32 1.89 935.02 MWD+IFR-AK-CAZ-SC(4) 3,608.38 60.35 99.16 3,120.18 2,965.47 355.51 1,136.45 5,928,007.59 462,055.36 1.35 1,016.69 MWD+IFR-AK-CAZ-SC(4) 3,703.06 63.18 100.05 3,164.97 3,010.26 341.58 1,218.68 5,927,993.24 462,137.51 3.10 1,099.85 MWD+IFR-AK-CAZ-SC(4) 3,797.41 66.02 98.97 3,205.43 3,050.72 327.51 1,302.73 5,927,978.74 462,221.48 3.18 1,184.80 MWD+IFR-AK-CAZ-SC(4) 3,891.81 68.53 98.37 3,241.90 3,087.19 314.39 1,388.80 5,927,965.17 462,307.47 2.72 1,271.49 MWD+IFR-AK-CAZ-SC(4) 3,987.83 71.42 97.73 3,274.78 3,120.07 301.77 1,478.12 5,927,952.08 462,396.71 3.07 1,361.21 MWD+IFR-AK-CAZ-SC(4) 4,082.12 74.16 98.10 3,302.67 3,147.96 289.36 1,567.32 5,927,939.22 462,485.84 2.93 1,450.76 MWD+IFR-AK-CAZ-SC(4) 4,176.24 73.87 98.87 3,328.59 3,173.88 276.01 1,656.81 5,927,925.41 462,575.25 0.84 1,540.82 MWD+IFR-AK-CAZ-SC(4) 4,271.64 73.93 99.95 3,355.05 3,200.34 261.03 1,747.23 5,927,909.96 462,665.59 1.09 1,632.19 MWD+IFR-AK-CAZ-SC(4) 4,365.03 73.93 101.50 3,380.90 3,226.19 244.33 1,835.40 5,927,892.80 462,753.66 1.59 1,721.78 MWD+IFR-AK-CAZ-SC(4) 4,460.49 73.90 102.79 3,407.35 3,252.64 225.03 1,925.07 5,927,873.04 462,843.22 1.30 1,813.45 MWD+IFR-AK-CAZ-SC(4) 4,554.08 73.90 102.49 3,433.30 3,278.59 205.35 2,012.81 5,927,852.91 462,930.85 0.31 1,903.34 MWD+IFR-AK-CAZ-SC(4) 4,648.41 73.86 102.63 3,459.50 3,304.79 185.65 2,101.26 5,927,832.75 463,019.19 0.15 1,993.94 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 4:14:08PM Page 3 COMPASS 5000.1 Build 65 • • . Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9©154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 4,742.83 73.93 102.71 3,485.69 3,330.98 165.75 2,189.77 5,927,812.40 463,107.58 0.11 2,084.63 MWD+IFR-AK-CAZ-SC(4) 4,837.94 73.93 102.50 3,512.01 3,357.30 145.81 2,278.96 5,927,792.00 463,196.66 0.21 2,175.99 MWD+IFR-AK-CAZ-SC(4) 4,932.46 73.84 102.67 3,538.25 3,383.54 126.02 2,367.58 5,927,771.75 463,285.17 0.20 2,266.77 MWD+IFR-AK-CAZ-SC(4) 5,026.70 73.81 100.70 3,564.51 3,409.80 107.69 2,456.21 5,927,752.97 463,373,69 2.01 2,357.20 MWD+IFR-AK-CAZ-SC(4) 5,216.11 73.81 96.99 3,617.33 3,462.62 79.73 2,635.91 5,927,724.08 463,553.23 1.88 2,538.33 MWD+IFR-AK-CAZ-SC(4) 5,310.55 73.84 96.98 3,643.64 3,488.93 68.70 2,725.94 5,927,712.58 463,643.19 0.03 2,628.35 MWD+IFR-AK-CAZ-SC(4) 5,405.55 73.93 97.60 3,670.01 3,515.30 57.11 2,816.47 5,927,700.53 463,733.65 0.63 2,718.99 MWD+IFR-AK-CAZ-SC(4) 5,500.48 73.90 98.78 3,696.31 3,541.60 44.12 2,906.75 5,927,687.07 463,823.85 1.19 2,809.73 MWD+IFR-AK-CAZ-SC(4) 5,595.51 73.99 99.82 3,722.60 3,567.89 29.36 2,996.87 5,927,671.85 463,913.89 1.06 2,900.75 MWD+IFR-AK-CAZ-SC(4) 5,690.08 73.99 101.56 3,748.68 3,593.97 12.50 3,086.19 5,927,654.53 464,003.11 1.77 2,991.50 MWD+IFR-AK-CAZ-SC(4) 5,784.05 74.47 103.73 3,774.22 3,619.51 -7.30 3,174.43 5,927,634.28 464,091.23 2.28 3,081.90 MW D+I FR-AK-CAZ-SC(4) 5,879.61 74.74 105.79 3,799.59 3,644.88 -30.77 3,263.51 5,927,610.35 464,180.18 2.10 3,174.01 MWD+IFR-AK-CAZ-SC(4) 5,969.07 74.29 106.37 3,823.48 3,668.77 -54.65 3,346.35 5,927,586.04 464,262.89 0.80 3,260.17 MWD+IFR-AK-CAZ-SC(4) 6,068.42 74.01 105.68 3,850.61 3,695.90 -81.03 3,438.21 5,927,559.19 464,354.60 0.73 3,355.68 MWD+IFR-AK-CAZ-SC(4) 6,162.52 72.93 106.77 3,877.39 3,722.68 -106.23 3,524.82 5,927,533.54 464,441.08 1.60 3,445.82 MWD+IFR-AK-CAZ-SC(4) 6,256.49 73.12 106.53 3,904.82 3,750.11 -131.98 3,610.93 5,927,507.34 464,527.04 0.32 3,535.60 MWD+IFR-AK-CAZ-SC(4) 6,352.40 73.10 107.04 3,932.69 3,777.98 -158.49 3,698.79 5,927,480.39 464,614.76 0.51 3,627.27 MWD+IFR-AK-CAZ-SC(4) 6,447.45 73.04 107.31 3,960.37 3,805.66 -185.34 3,785.67 5,927,453.09 464,701.48 0.28 3,718.06 MWD+IFR-AK-CAZ-SC(4) 6,541.66 73.00 106.94 3,987.88 3,833.17 -211.87 3,871.78 5,927,426.12 464,787.44 0.38 3,808.03 MWD+IFR-AK-CAZ-SC(4) 6,636.18 73.14 107.05 4,015.40 3,860.69 -238.30 3,958.25 5,927,399.24 464,873.77 0.19 3,898.33 MWD+IFR-AK-CAZ-SC(4) 6,730.84 74.61 106.06 4,041.69 3,886.98 -264.20 4,045.42 5,927,372.89 464,960.79 1.85 3,989.17 MWD+I FR-AK-CAZ-SC(4) 6,825.55 74.53 106.33 4,066.89 3,912.18 -289.67 4,133.09 5,927,346.97 465,048.32 0.29 4,080.40 MWD+IFR-AK-CAZ-SC(4) 6,920.11 74.61 106.13 4,092.05 3,937.34 -315.14 4,220.61 5,927,321.05 465,135.70 0.22 4,171.48 MWD+IFR-AK-CAZ-SC(4) 7,015.32 74.64 107.25 4,117.30 3,962.59 -341.51 4,308.54 5,927,294.23 465,223.49 1.13 4,263.18 MWD+IFR-AK-CAZ-SC(4) 7,110.53 74.59 107.69 4,142.55 3,987.84 -369.07 4,396.11 5,927,266.22 465,310.90 0.45 4,354.81 MWD+IFR-AK-CAZ-SC(4) 7,205.57 74.20 107.48 4,168.12 4,013.41 -396.72 4,483.37 5,927,238.12 465,398.01 0.46 4,446.17 MWD+IFR-AK-CAZ-SC(4) 7,300.00 73.99 107.27 4,194.00 4,039.29 -423.84 4,570.04 5,927,210.55 465,484.53 0.31 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,395.01 74.08 106.40 4,220.13 4,065.42 -450.30 4,657.47 5,927,183.65 465,571.81 0.89 4,628.06 MWD+IFR-AK-CAZ-SC(4) 7,489.62 74.05 105.25 4,246.11 4,091.40 -475.11 4,744.99 5,927,158.39 465,659.20 1.17 4,718.98 MWD+IFR-AK-CAZ-SC(4) 7,583.63 74.05 103.99 4,271.94 4,117.23 -497.92 4,832.45 5,927,135.13 465,746.53 1.29 4,809.37 MWD+IFR-AK-CAZ-SC(4) 7,678.34 74.08 103.79 4,297.94 4,143.23 -519.78 4,920.86 5,927,112.81 465,834.82 0.21 4,900.44 MWD+I FR-AK-CAZ-SC(4) 7,772.93 74.08 105.19 4,323.89 4,169.18 -542.54 5,008.93 5,927,089.60 465,922.75 1.42 4,991.39 MWD+IFR-AK-CAZ-SC(4) 7,867.45 74.11 106.30 4,349.79 4,195.08 -567.21 5,096.42 5,927,064.48 466,010.11 1.13 5,082.25 MWD+IFR-AK-CAZ-SC(4) 7,962.19 74.08 108.75 4,375.76 4,221.05 -594.64 5,183.29 5,927,036.60 466,096.83 2.49 5,173.18 MWD+IFR-AK-CAZ-SC(4) 8,056.39 74.19 109.40 4,401.51 4,246.80 -624.25 5,268.93 5,927,006.55 466,182.30 0.67 5,263.44 MWD+IFR-AK-CAZ-SC(4) 8,150.73 73.61 109.64 4,427.67 4,272.96 -654.54 5,354.36 5,926,975.82 466,267.57 0.66 5,353.66 MWD+IFR-AK-CAZ-SC(4) 8,244.95 73.69 110.01 4,454.20 4,299.49 -685.20 5,439.41 5,926,944.72 466,352.45 0.39 5,443.60 MWD+IFR-AK-CAZ-SC(4) 8,340.09 73.58 109.25 4,481.00 4,326.29 -715.87 5,525.39 5,926,913.62 466,438.26 0.78 5,534.44 MWD+IFR-AK-CAZ-SC(4) 8,434.93 73.58 109.73 4,507.81 4,353.10 -746.22 5,611.15 5,926,882.82 466,523.85 0.49 5,625.00 MWD+IFR-AK-CAZ-SC(4) 8,529.42 73.63 108.51 4,534.49 4,379.78 -775.91 5,696.79 5,926,852.69 466,609.34 1.24 5,715.28 MWD+IFR-AK-CAZ-SC(4) 8,623.95 73.61 108.73 4,561.14 4,406.43 -804.87 5,782.74 5,926,823.29 466,695.12 0.22 5,805.68 MWD+IFR-AK-CAZ-SC(4) 8,718.56 74.15 109.08 4,587.41 4,432.70 -834.32 5,868.73 5,926,793.40 466,780.95 0.67 5,896.24 MWD+IFR-AK-CAZ-SC(4) 8,813.60 74.17 109.08 4,613.35 4,458.64 -864.20 5,955.13 5,926,763.07 466,867.19 0.02 5,987.31 MWD+IFR-AK-CAZ-SC(4) 8,908.18 74.08 107.73 4,639.23 4,484.52 -892.93 6,041.45 5,926,733.90 466,953.35 1.38 6,078.01 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 4:14:08PM Page 4 COMPASS 5000.1 Build 65 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,003.06 74.20 107.04 4,665.16 4,510.45 -920.20 6,128.55 5,926,706.19 467,040.30 0.71 6,169.12 MWD+IFR-AK-CAZ-SC(4) 9,097.82 74.12 105.89 4,691.02 4,536.31 -946.03 6,215.97 5,926,679.90 467,127.58 1.17 6,260.20 MWD+IFR-AK-CAZ-SC(4) 9,192.11 74.14 106.72 4,716.81 4,562.10 -971.50 6,303.02 5,926,653.99 467,214.48 0.85 6,350.82 MWD+IFR-AK-CAZ-SC(4) 9,287.37 74.03 107.00 4,742.93 4,588.22 -998.07 6,390.69 5,926,626.97 467,302.01 0.31 6,442.31 MWD+IFR-AK-CAZ-SC(4) 9,381.66 74.17 106.79 4,768.76 4,614.05 -1,024.42 6,477.46 5,926,600.17 467,388.63 0.26 6,532.88 MWD+I FR-AK-CAZ-SC(4) 9,476.49 74.14 106.76 4,794.65 4,639.94 -1,050.75 6,564.80 5,926,573.39 467,475.83 0.04 6,624.00 MWD+IFR-AK-CAZ-SC(4) 9,571.44 74.14 108.21 4,820.60 4,665.89 -1,078.19 6,651.92 5,926,545.50 467,562.79 1.47 6,715.16 MWD+IFR-AK-CAZ-SC(4) 9,666.22 74.08 107.78 4,846.55 4,691.84 -1,106.35 6,738.61 5,926,516.89 467,649.33 0.44 6,806.10 MWD+IFR-AK-CAZ-SC(4) 9,760.66 74.08 108.10 4,872.46 4,717.75 -1,134.33 6,825.02 5,926,488.48 467,735.58 0.33 6,896.70 MWD+IFR-AK-CAZ-SC(4) 9,855.63 74.14 107.42 4,898.46 4,743.75 -1,162.19 6,912.00 5,926,460.17 467,822.41 0.69 6,987.85 MWD+IFR-AK-CAZ-SC(4) 9,949.63 74.02 108.17 4,924.24 4,769.53 -1,189.81 6,998.07 5,926,432.10 467,908.33 0.78 7,078.04 MWD+IFR-AK-CAZ-SC(4) 10,044.46 74.05 107.26 4,950.33 4,795.62 -1,217.56 7,084.92 5,926,403.91 467,995.02 0.92 7,169.02 MWD+IF R-AK-CAZ-SC(4) 10,139.34 74.47 105.93 4,976.06 4,821.35 -1,243.64 7,172.44 5,926,377.38 468,082.39 1.42 7,260.25 MWD+IFR-AK-CAZ-SC(4) 10,233.24 75.06 105.16 5,000.74 4,846.03 -1,267.92 7,259.72 5,926,352.65 468,169.54 1.01 7,350.81 MWD+IFR-AK-CAZ-SC(4) 10,327.81 75.54 106.36 5,024.74 4,870.03 -1,292.76 7,347.76 5,926,327.35 468,257.44 1.33 7,442.24 MWD+IFR-AK-CAZ-SC(4) 10,422.74 77.50 106.27 5,046.87 4,892.16 -1,318.69 7,436.35 5,926,300.97 468,345.89 2.07 7,534.48 MWD+IFR-AK-CAZ-SC(4) 10,516.49 80.09 105.40 5,065.08 4,910.37 -1,343.78 7,524.81 5,926,275.42 468,434.21 2.91 7,626.39 MWD+IF R-AK-CAZ-SC(4) 10,611.75 80.49 104.69 5,081.15 4,926.44 -1,368.15 7,615.49 5,926,250.58 468,524.75 0.85 7,720.26 MWD+IF R-AK-CAZ-SC(4) 10,706.46 80.66 105.36 5,096.66 4,941.95 -1,392.37 7,705.73 5,926,225.90 468,614.86 0.72 7,813.68 MWD+I FR-AK-CAZ-SC(4) 10,801.55 80.06 105.18 5,112.58 4,957.87 -1,417.06 7,796.16 5,926,200.74 468,705.15 0.66 7,907.40 MWD+IFR-AK-CAZ-SC(4) 10,896.53 80.05 106.72 5,128.99 4,974.28 -1,442.77 7,886.11 5,926,174.57 468,794.96 1.60 8,000.90 MWD+IFR-AK-CAZ-SC(4) 10,990.82 79.03 107.30 5,146.10 4,991.39 -1,469.90 7,974.78 5,926,146.99 468,883.47 1.24 8,093.49 MWD+IFR-AK-CAZ-SC(4) 11,084.14 79.05 107.39 5,163.85 5,009.14 -1,497.21 8,062.23 5,926,119.23 468,970.78 0.10 8,184.95 MWD+IFR-AK-CAZ-SC(4) 11,179.03 79.05 107.82 5,181.87 5,027.16 -1,525.39 8,151.03 5,926,090.60 469,059.42 0.44 8,277.93 MWD+IFR-AK-CAZ-SC(4) 11,274.58 79.13 108.75 5,199.96 5,045.25 -1,554.82 8,240.11 5,926,060.70 469,148.34 0.96 8,371.49 MWD+IF R-AK-CAZ-SC(4) 11,369.07 79.10 108.92 5,217.80 5,063.09 -1,584.78 8,327.93 5,926,030.30 469,236.00 0.18 8,463.95 MWD+IF R-AK-CAZ-SC(4) 11,463.44 79.10 109.08 5,235.64 5,080.93 -1,614.95 8,415.55 5,925,999.68 469,323.45 0.17 8,556.27 MWD+IF R-AK-CAZ-SC(4) 11,557.78 79.19 108.17 5,253.41 5,098.70 -1,644.54 8,503.35 5,925,969.63 469,411.09 0.95 8,648.62 MWD+IFR-AK-CAZ-SC(4) 11,652.59 79.64 108.50 5,270.83 5,116.12 -1,673.86 8,591.82 5,925,939.86 469,499.39 0.59 8,741.55 MWD+IFR-AK-CAZ-SC(4) 11,748.14 79.57 108.75 5,288.07 5,133.36 -1,703.87 8,680.88 5,925,909.39 469,588.28 0.27 8,835.22 MWD+I F R-AK-CAZ-SC(4) 11,842.29 79.51 108.70 5,305.16 5,150.45 -1,733.59 8,768.56 5,925,879.22 469,675.80 0.08 8,927.49 MWD+IFR-AK-CAZ-SC(4) 11,936.81 79.57 110.94 5,322.32 5,167.61 -1,765.11 8,856.00 5,925,847.25 469,763.07 2.33 9,019.96 MWD+IFR-AK-CAZ-SC(4) 12,031.50 79.74 112.93 5,339.33 5,184.62 -1,799.90 8,942.40 5,925,812.02 469,849.28 2.08 9,112.21 MWD+IFR-AK-CAZ-SC(4) 12,126.71 79.98 115.56 5,356.09 5,201.38 -1,838.39 9,027.85 5,925,773.09 469,934.52 2.73 9,204.43 MWD+IFR-AK-CAZ-SC(4) 12,187.00 80.08 118.18 5,366.53 5.211.82 -1,865.22 9,080.81 5,925,745.99 469,987.34 4.28 9,262.31 MWD+IFR-AK-CAZ-SC(5) 7-518"x 9-7/8" 12,220.64 80.14 119.64 5,372.31 5,217.60 -1,881.24 9,109.82 5,925,729.82 470,016.26 4.28 9,294.33 MWD+IFR-AK-CAZ-SC(5) 12,270.43 81.20 122.55 5,380.39 5,225.68 -1,906.61 9,151.89 5,925,704.23 470,058.19 6.15 9,341.29 MWD+IFR-AK-CAZ-SC(5) 12,315.32 81.82 125.70 5,387.02 5,232.31 -1,931.52 9,188.64 5,925,679.14 470,094.81 7.08 9,382.97 MWD+IFR-AK-CAZ-SC(5) 12,368.00 81.76 129.46 5,394.54 5,239.83 -1,963.31 9,229.95 5,925,647.14 470,135.95 7.07 9,430.75 MWD+IFR-AK-CAZ-SC(5) 12,410.45 81.82 132.75 5,400.61 5,245.90 -1,990.93 9,261.60 5,925,619.36 470,167.46 7.67 9,468.14 MWD+IFR-AK-CAZ-SC(5) 12,462.71 81.75 136.63 5,408.08 5,253.37 -2,027.30 9,298.37 5,925,582.80 470,204.03 7.35 9,512.61 MWD+IFR-AK-CAZ-SC(5) 12,505.42 81.75 138.34 5,414.20 5,259.49 -2,058.45 9,326.93 5,925,551.50 470,232.43 3.96 9,547.87 MWD+IFR-AK-CAZ-SC(5) 12,561.12 81.89 139.57 5,422.13 5,267.42 -2,100.03 9,363.13 5,925,509.74 470,268.41 2.20 9,593.05 MWD+IFR-AK-CAZ-SC(5) 5/7/2015 4:14:08PM Page 5 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,600.04 82.20 140.77 5,427.52 5,272.81 -2,129.63 9,387.82 5,925,480.02 470,292.95 3.16 9,624.17 MWD+IFR-AK-CAZ-SC(5) 12,695.01 83.59 144.09 5,439.27 5,284.56 -2,204.32 9,445.27 5,925,405.04 470,350.00 3.77 9,697.98 MWD+IFR-AK-CAZ-SC(5) 12,789.71 84.38 147.85 5,449.19 5,294.48 -2,282.36 9,497.96 5,925,326.74 470,402.28 4.04 9,767.98 MWD+IFR-AK-CAZ-SC(5) 12,884.18 84.68 150.81 5,458.20 5,303.49 -2,363.23 9,545.93 5,925,245.62 470,449.82 3.14 9,834.09 MWD+IFR-AK-CAZ-SC(5) 12,979.32 86.07 154.40 5,465.87 5,311.16 -2,447.41 9,589.55 5,925,161.23 470,493.00 4.03 9,896.78 MWD+I F R-AK-CAZ-SC(5) 13,075.10 87.61 157.90 5,471.16 5,316.45 -2,534.87 9,628.21 5,925,073.58 470,531.21 3.99 9,955.45 MWD+IFR-AK-CAZ-SC(5) 13,170.26 85.12 158.58 5,477.19 5,322.48 -2,623.06 9,663.41 5,924,985.22 470,565.95 2.71 10,010.94 MWD+IFR-AK-CAZ-SC(5) 13,265.22 84.54 160.19 5,485.75 5,331.04 -2,711.57 9,696.71 5,924,896.54 470,598.79 1.80 10,064.67 MWD+IFR-AK-CAZ-SC(5) 13,359.96 84.99 161.86 5,494.39 5,339.68 -2,800.79 9,727.38 5,924,807.18 470,629.00 1.82 10,116.01 MWD+IFR-AK-CAZ-SC(5) 13,454.46 86.46 164.80 5,501.44 5,346.73 -2,891.05 9,754.41 5,924,716.78 470,655.55 3.47 10,164.07 MWD+IFR-AK-CAZ-SC(5) 13,549.07 86.81 164.19 5,506.99 5,352.28 -2,982.06 9,779.66 5,924,625.65 470,680.33 0.74 10,210.59 MWD+IFR-AK-CAZ-SC(5) 13,644.37 88.20 162.78 5,511.14 5,356.43 -3,073.34 9,806.72 5,924,534.25 470,706.92 2.08 10,258.93 MWD+I F R-AK-CAZ-SC(5) 13,739.33 88.68 160.44 5,513.72 5,359.01 -3,163.41 9,836.67 5,924,444.03 470,736.39 2.51 10,309.78 MWD+IFR-AK-CAZ-SC(5) 13,833.72 88.56 158.34 5,516.00 5,361.29 -3,251.73 9,869.88 5,924,355.55 470,769.15 2.23 10,363.37 MWD+IFR-AK-CAZSC(5) 13,928.88 89.57 157.40 5,517.55 5,362.84 -3,339.86 9,905.73 5,924,267.24 470,804.53 1.45 10,419.47 MWD+IFR-AK-CAZSC(5) 14,023.98 91.07 152.03 5,517.02 5,362.31 -3,425.82 9,946.33 5,924,181.08 470,844.68 5.86 10,479.66 MWD+IFR-AK-CAZ-SC(5) 14,118.00 90.87 152.78 5,515.43 5,360.72 -3,509.13 9,989.87 5,924,097.56 470,887.79 0.83 10,542.07 MWD+IFR-AK-CAZ-SC(5) 14,212.79 90.60 156.23 5,514.21 5,359.50 -3,594.67 10,030.66 5,924,011.82 470,928.13 3.65 10,602.34 MWD+IFR-AK-CAZ-SC(5) 14,307.10 90.49 156.57 5,513.31 5,358.60 -3,681.09 10,068.42 5,923,925.21 470,965.44 0.38 10,659.88 MWD+IFR-AK-CAZ-SC(5) 14,402.56 89.52 157.16 5,513.31 5,358.60 -3,768.87 10,105.92 5,923,837.25 471,002.48 1.19 10,717.51 MWD+I F R-AK-CAZ-SC(5) 14,497.09 89.60 160.81 5,514.03 5,359.32 -3,857.10 10,139.82 5,923,748.85 471,035.92 3.86 10,771.74 MWD+IFR-AK-CAZ-SC(5) 14,592.25 89.05 162.79 5,515.15 5,360.44 -3,947.48 10,169.54 5,923,658.32 471,065.16 2.16 10,822.44 MWD+IFR-AK-CAZ-SC(5) 14,686.70 89.19 162.31 5,516.60 5,361.89 -4,037.58 10,197.85 5,923,568.09 471,093.01 0.53 10,871.71 MWD+IFR-AK-CAZ-SC(5) 14,781.82 89.43 160.62 5,517.75 5,363.04 -4,127.75 10,228.09 5,923,477.77 471,122.78 1.79 10,922.86 MWD+IFR-AK-CAZ-SC(5) 14,876.92 89.16 157.40 5,518.92 5,364.21 -4,216.52 10,262.15 5,923,388.83 471,156.37 3.40 10,977.39 MWD+IFR-AK-CAZ-SC(5) 14,930.00 88.53 156.63 5,519.99 5,365.28 -4,265.38 10,282.87 5,923,339.88 471,176.84 1.87 11,009.31 MWD+IF R-AK-CAZ-SC(5) 14,990.00 88.53 156.63 5,521.53 5,366.82 -4,320.44 10,306.66 5,923,284.70 471,200.34 0.00 11,045.72 PROJECTED to TD ( 4 1/2"x 6-3/4., 5/7/2015 4:14:08PM Page 6 COMPASS 5000.1 Build 65 Lb810 • • 215006 RECEIVED MAY 12 2015 AOGCC FINAL ) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad 2L-316 Definitive Survey Report NAD 83 07 May, 2015 • III - Schlurnberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2L-316 Well Position +N/-S 0.00 usft Northing: 5,927,407.22 usfi Latitude: 70°12'46.764 N +E/-W 0.00 usft Easting: 1,600,950.94 usfi Longitude: 150°19'5.859 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 114.90 usft Iellbore 2L-316 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 4/1/2015 18.65 80.78 57,541 Design 2L-316 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.81 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.81 0.00 0.00 104.00 Survey Program Date 5/7/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.40 919.36 2L-316 Srvy#1 GYD-GC-SS(2L-316) GYD-GC-SS Gyrodata gyro single shots 4/14/2015 9:01 949.74 2,446.79 2L-316 Srvy#2 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/14/2015 9:1: 2,489.32 2,566.91 2L-316 Srvy#3 MWD+IFR-AK-CAZ-SC(INC+TREND Inclinometer+known azi trend 4/20/2015 4:5: 2,660.98 12,126.71 2L-316 Srvy#4 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/5/2015 4:42, 1 12,220.64 14,930.00 2L-316 Srvy#5 MWD+IFR-AK-CAZ-SC(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2015 11:15 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.81 0.00 0.00 39.81 -114.90 0.00 0.00 5,927,407.22 1,600,950.94 0.00 0.00 UNDEFINED 81.25 0.37 252.18 81.25 -73.46 -0.04 -0.13 5,927,407.18 1,600,950.81 0.89 -0.11 GYD-GC-SS(1) 143.39 0.91 269.94 143.39 -11.32 -0.10 -0.81 5,927,407.12 1,600,950.13 0.92 -0.76 GYD-GC-SS(1) 165.31 0.88 277.83 165.30 10.59 -0.08 -1.15 5,927,407.15 1,600,949.79 0.58 -1.10 GYD-GC-SS(1) 204.28 0.67 281.24 204.27 49.56 0.01 -1.67 5,927,407.23 1,600,949.27 0.55 -1.62 GYD-GC-SS(1) 262.07 1.21 309.23 262.05 107.34 0.46 -2.48 5,927,407.69 1,600,948.47 1.20 -2.51 GYD-GC-SS(1) 310.17 2.36 328.20 310.13 155.42 1.62 -3.39 5,927,408.86 1,600,947.56 2.66 -3.68 GYD-GC-SS(1) 356.00 2.68 330.55 355.91 201.20 3.35 -4.42 5,927,410.60 1,600,946.54 0.73 -5.10 GYD-GC-SS(1) 449.15 3.85 340.21 448.91 294.20 8.19 -6.55 5,927,415.45 1,600,944.44 1.38 -8.33 GYD-GC-SS(1) 542.74 4.66 351.13 542.24 387.53 14.91 -8.20 5,927,422.17 1,600,942.82 1.22 -11.56 GYD-GC-SS(1) 635.64 5.69 357.04 634.76 480.05 23.23 -9.02 5,927,430.50 1,600,942.05 1.25 -14.37 GYD-GC-SS(1) 730.84 6.92 1.62 729.39 574.68 33.68 -9.10 5,927,440.94 1,600,942.02 1.39 -16.97 GYD-GC-SS(1) 823.69 8.81 5.31 821.36 666.65 46.35 -8.28 5,927,453.61 1,600,942.90 2.11 -19.25 GYD-GC-SS(1) 919.36 9.60 5.74 915.80 761.09 61.59 -6.80 5,927,468.83 1,600,944.46 0.83 -21.50 GYD-GC-SS(1) 5/7/2015 3:06:45PM Page 2 COMPASS 5000.1 Build 65 • • „,. Schlumberger ConocoPhi lips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 949.74 9.53 7.17 945.76 791.05 66.60 -6.24 5,927,473.85 1,600,945.05 0.82 -22.16 MWD+IFR-AK-CAZ-SC(2) 975.62 9.22 7.22 971.29 816.58 70.78 -5.71 5,927,478.03 1,600,945.60 1.20 -22.66 MWD+I FR-AK-CAZ-SC(2) 1,073.18 11.45 7.05 1,067.26 912.55 88.15 -3.54 5,927,495.38 1,600,947.86 2.29 -24.76 MWD+IFR-AK-CAZ-SC(2) 1,168.44 13.82 6.16 1,160.21 1,005.50 108.85 -1.16 5,927,516.06 1,600,950.35 2.50 -27.46 MWD+IFR-AK-CAZ-SC(2) 1,262.37 14.93 7.67 1,251.20 1,096.49 132.00 1.66 5,927,539.19 1,600,953.29 1.25 -30.32 MWD+IFR-AK-CAZ-SC(2) 1,356.60 16.06 9.98 1,342.00 1,187.29 156.86 5.54 5,927,564.04 1,600,957.30 1.37 -32.57 MWD+IFR-AK-CAZ-SC(2) 1,451.64 17.26 12.40 1,433.05 1,278.34 183.58 10.85 5,927,590.73 1,600,962.75 1.46 -33.89 MWD+IFR-AK-CAZ-SC(2) 1,546.19 19.18 17.08 1,522.86 1,368.15 212.13 18.42 5,927,619.23 1,600,970.47 2.55 -33.44 MWD+IFR-AK-CAZ-SC(2) 1,640.48 20.82 22.38 1,611.47 1,456.76 242.44 29.35 5,927,649.48 1,600,981.56 2.59 -30.17 MWD+IFR-AK-CAZ-SC(2) 1,736.51 21.25 27.75 1,701.11 1,546.40 273.62 43.96 5,927,680.58 1,600,996.32 2.06 -23.55 MWD+IFR-AK-CAZ-SC(2) 1,831.04 22.16 38.74 1,788.97 1,634.26 302.70 63.10 5,927,709.56 1,601,015.61 4.40 -12.01 MWD+IFR-AK-CAZ-SC(2) 1,925.09 22.61 49.44 1,875.97 1,721.26 328.30 87.94 5,927,735.03 1,601,040.59 4.35 5.91 MWD+IFR-AK-CAZ-SC(2) 2,021.02 23.03 58.24 1,964.42 1,809.71 350.18 117.92 5,927,756.74 1,601,070.67 3.58 29.70 MWD+IFR-AK-CAZ-SC(2) 2,115.13 24.07 68.17 2,050.72 1,896.01 367.01 151.40 5,927,773.40 1,601,104.24 4.35 58.11 MWD+IFR-AK-CAZ-SC(2) 2,209.67 25.95 78.42 2,136.43 1,981.72 378.34 189.58 5,927,784.53 1,601,142.48 4.99 92.42 MWD+IFR-AK-CAZ-SC(2) 2,304.44 25.96 83.60 2,221.66 2,066.95 384.81 230.51 5,927,790.79 1,601,183.44 2.39 130.57 MWD+IFR-AK-CAZ-SC(2) 2,398.42 28.78 87.30 2,305.11 2,150.40 388.17 273.56 5,927,793.92 1,601,226.50 3.50 171.53 MWD+IFR-AK-CAZ-SC(2) 2,446.79 31.81 88.65 2,346.87 2,192.16 389.02 297.94 5,927,794.64 1,601,250.88 6.42 194.98 MWD+IFR-AK-CAZ-SC(2) 2,489.32 32.30 88.65 2,382.92 2,228.21 389.55 320.51 5,927,795.06 1,601,273.45 1.15 216.75 INC+TREND(3) 2,518.00 32.58 88.78 2,407.12 2,252.41 389.90 335.89 5,927,795.32 1,601,288.83 1.01 231.59 INC+TREND(3) 10 3/4"x 13-1/2 2,566.91 33.06 89.00 2,448.23 2,293.52 390.41 362.39 5,927,795.69 1,601,315.33 1.01 257.18 INC+TREND(3) 2,660.98 35.27 85.95 2,526.06 2,371.35 392.78 415.15 5,927,797.78 1,601,368.10 2.97 307.80 MWD+IFR-AK-CAZ-SC(4) 2,755.55 37.66 84.54 2,602.12 2,447.41 397.46 471.15 5,927,802.17 1,601,424.12 2.68 361.01 MWD+IFR-AK-CAZ-SC(4) 2,850.56 40.21 85.14 2,676.01 2,521.30 402.82 530.62 5,927,807.22 1,601,483.60 2.71 417.40 MWD+IFR-AK-CAZ-SC(4) 2,945.42 44.41 90.07 2,746.17 2,591.46 405.37 594.36 5,927,809.44 1,601,547.36 5.64 478.64 MWD+IFR-AK-CAZ-SC(4) 3,040.52 49.34 91.81 2,811.16 2,656.45 404.19 663.74 5,927,807.90 1,601,616.72 5.35 546.24 MWD+IFR-AK-CAZ-SC(4) 3,134.59 53.46 93.69 2,869.84 2,715.13 400.63 737.15 5,927,803.95 1,601,690.10 4.65 618.33 MWD+IFR-AK-CAZ-SC(4) 3,229.81 56.31 95.87 2,924.61 2,769.90 394.12 814.75 5,927,797.03 1,601,767.66 3.53 695.20 MWD+IFR-AK-CAZSC(4) 3,324.34 58.62 95.82 2,975.45 2,820.74 386.00 894.02 5,927,788.51 1,601,846.88 2.44 774.08 MWD+IFR-AK-CAZ-SC(4) 3,418.58 59.06 95.99 3,024.21 2,869.50 377.70 974.24 5,927,779.79 1,601,927.04 0.49 853.92 MWD+IFR-AK-CAZ-SC(4) 3,513.61 59.55 98.00 3,072.72 2,918.01 367.75 1,055.34 5,927,769.41 1,602,008.08 1.89 935.02 MWD+IFR-AK-CAZ-SC(4) 3,608.38 60.35 99.16 3,120.18 2,965.47 355.51 1,136.45 5,927,756.75 1,602,089.12 1.35 1,016.69 MWD+IFR-AK-CAZ-SC(4) 3,703.06 63.18 100.05 3,164.97 3,010.26 341.58 1,218.68 5,927,742.40 1,602,171.27 3.10 1,099.85 MWD+IFR-AK-CAZ-SC(4) 3,797.41 66.02 98.97 3,205.43 3,050.72 327.51 1,302.73 5,927,727.89 1,602,255.24 3.18 1,184.80 MWD+IFR-AK-CAZ-SC(4) 3,891.81 68.53 98.37 3,241.90 3,087.19 314.39 1,388.80 5,927,714.32 1,602,341.23 2.72 1,271.49 MWD+IFR-AK-CAZ-SC(4) 3,987.83 71.42 97.73 3,274.78 3,120.07 301.77 1,478.12 5,927,701.23 1,602,430.47 3.07 1,361.21 MWD+IFR-AK-CAZ-SC(4) 4,082.12 74.16 98.10 3,302.67 3,147.96 289.36 1,567.32 5,927,688.36 1,602,519.60 2.93 1,450.76 MWD+IFR-AK-CAZ-SC(4) 4,176.24 73.87 98.87 3,328.59 3,173.88 276.01 1,656.81 5,927,674.54 1,602,609.01 0.84 1,540.82 MWD+IFR-AK-CAZ-SC(4) 4,271.64 73.93 99.95 3,355.05 3,200.34 261.03 1,747.23 5,927,659.08 1,602,699.34 1.09 1,632.19 MWD+IFR-AK-CAZ-SC(4) 4,365.03 73.93 101.50 3,380.90 3,226.19 244.33 1,835.40 5,927,641.93 1,602,787.42 1.59 1,721.78 MWD+IFR-AK-CAZSC(4) 4,460.49 73.90 102.79 3,407.35 3,252.64 225.03 1,925.07 5,927,622.16 1,602,876.97 1.30 1,813.45 MWD+IFR-AK-CAZ-SC(4) 4,554.08 73.90 102.49 3,433.30 3,278.59 205.35 2,012.81 5,927,602.03 1,602,964.60 0.31 1,903.34 MWD+IFR-AK-CAZ-SC(4) 4,648.41 73.86 102.63 3,459.50 3,304.79 185.65 2,101.26 5,927,581.86 1,603,052.94 0.15 1,993.94 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 3:06:45PM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,742.83 73.93 102.71 3,485.69 3,330.98 165.75 2,189.77 5,927,561.51 1,603,141.33 0.11 2,084.63 MWD+IFR-AK-CAZ-SC(4) 4,837.94 73.93 102.50 3,512.01 3,357.30 145.81 2,278.96 5,927,541.10 1,603,230.41 0.21 2,175.99 MWD+IFR-AK-CAZ-SC(4) 4,932.46 73.84 102.67 3,538.25 3,383.54 126.02 2,367.58 5,927,520.85 1,603,318.92 0.20 2,266.77 MWD+IFR-AK-CAZ-SC(4) 5,026.70 73.81 100.70 3,564.51 3,409.80 107.69 2,456.21 5,927,502.06 1,603,407.44 2.01 2,357.20 MWD+IFR-AK-CAZ-SC(4) 5,216.11 73.81 96.99 3,617.33 3,462.62 79.73 2,635.91 5,927,473.16 1,603,586.97 1.88 2,538.33 MWD+IFR-AK-CAZ-SC(4) 5,310.55 73.84 96.98 3,643.64 3,488.93 68.70 2,725.94 5,927,461.66 1,603,676.93 0.03 2,628.35 MWD+IFR-AK-CAZ-SC(4) 5,405.55 73.93 97.60 3,670.01 3,515.30 57.11 2,816.47 5,927,449.61 1,603,767.39 0.63 2,718.99 MWD+IFR-AK-CAZ-SC(4) 5,500.48 73.90 98.78 3,696.31 3,541.60 44.12 2,906.75 5,927,436.14 1,603,857.60 1.19 2,809.73 MWD+IFR-AK-CAZ-SC(4) 5,595.51 73.99 99.82 3,722.60 3,567.89 29.36 2,996.87 5,927,420.92 1,603,947.63 1.06 2,900.75 MWD+IFR-AK-CAZ-SC(4) 5,690.08 73.99 101.56 3,748.68 3,593.97 12.50 3,086.19 5,927,403.59 1,604,036.85 1.77 2,991.50 MWD+IFR-AK-CAZ-SC(4) 5,784.05 74.47 103.73 3,774.22 3,619.51 -7.30 3,174.43 5,927,383.33 1,604,124.97 2.28 3,081.90 MWD+IFR-AK-CAZ-SC(4) 5,879.61 74.74 105.79 3,799.59 3,644.88 -30.77 3,263.51 5,927,359.40 1,604,213.93 2.10 3,174.01 MWD+IFR-AK-CAZ-SC(4) 5,969.07 74.29 106.37 3,823.48 3,668.77 -54.65 3,346.35 5,927,335.09 1,604,296.63 0.80 3,260.17 MWD+IFR-AK-CAZ-SC(4) 6,068.42 74.01 105.68 3,850.61 3,695.90 -81.03 3,438.21 5,927,308.23 1,604,388.34 0.73 3,355.68 MWD+IFR-AK-CAZ-SC(4) 6,162.52 72.93 106.77 3,877.39 3,722.68 -106.23 3,524.82 5,927,282.58 1,604,474.81 1.60 3,445.82 MWD+IFR-AK-CAZ-SC(4) 6,256.49 73.12 106.53 3,904.82 3,750.11 -131.98 3,610.93 5,927,256.38 1,604,560.78 0.32 3,535.60 MWD+IFR-AK-CAZ-SC(4) 6,352.40 73.10 107.04 3,932.69 3,777.98 -158.49 3,698.79 5,927,229.42 1,604,648.49 0.51 3,627.27 MWD+IFR-AK-CAZ-SC(4) 6,447.45 73.04 107.31 3,960.37 3,805.66 -185.34 3,785.67 5,927,202.12 1,604,735.22 0.28 3,718.06 MWD+IFR-AK-CAZ-SC(4) 6,541.66 73.00 106.94 3,987.88 3,833.17 -211.87 3,871.78 5,927,175.14 1,604,821.18 0.38 3,808.03 MWD+IFR-AK-CAZ-SC(4) 6,636.18 73.14 107.05 4,015.40 3,860.69 -238.30 3,958.25 5,927,148.26 1,604,907.50 0.19 3,898.33 MWD+IFR-AK-CAZ-SC(4) 6,730.84 74.61 106.06 4,041.69 3,886.98 -264.20 4,045.42 5,927,121.90 1,604,994.52 1.85 3,989.17 MWD+IFR-AK-CAZ-SC(4) 6,825.55 74.53 106.33 4,066.89 3,912.18 -289.67 4,133.09 5,927,095.98 1,605,082.05 0.29 4,080.40 MWD+IFR-AK-CAZ-SC(4) 6,920.11 74.61 106.13 4,092.05 3,937.34 -315.14 4,220.61 5,927,070.05 1,605,169.43 0.22 4,171.48 MWD+IFR-AK-CAZ-SC(4) 7,015.32 74.64 107.25 4,117.30 3,962.59 -341.51 4,308.54 5,927,043.23 1,605,257.22 1.13 4,263.18 MWD+IFR-AK-CAZ-SC(4) 7,110.53 74.59 107.69 4,142.55 3,987.84 -369.07 4,396.11 5,927,015.22 1,605,344.63 0.45 4,354.81 MWD+IFR-AK-CAZ-SC(4) 7,205.57 74.20 107.48 4,168.12 4,013.41 -396.72 4,483.37 5,926,987.11 1,605,431.73 0.46 4,446.17 MWD+IFR-AK-CAZ-SC(4) 7,300.00 73.99 107.27 4,194.00 4,039.29 -423.84 4,570.04 5,926,959.54 1,605,518.25 0.31 4,536.82 MWD+IFR-AK-CAZ-SC(4) 7,395.01 74.08 106.40 4,220.13 4,065.42 -450.30 4,657.47 5,926,932.63 1,605,605.53 0.89 4,628.06 MWD+IFR-AK-CAZ-SC(4) 7,489.62 74.05 105.25 4,246.11 4,091.40 -475.11 4,744.99 5,926,907.37 1,605,692.92 1.17 4,718.98 MWD+IFR-AK-CAZ-SC(4) 7,583.63 74.05 103.99 4,271.94 4,117.23 -497.92 4,832.45 5,926,884.10 1,605,780.25 1.29 4,809.37 MWD+IFR-AK-CAZ-SC(4) 7,678.34 74.08 103.79 4,297.94 4,143.23 -519.78 4,920.86 5,926,861.78 1,605,868.53 0.21 4,900.44 MWD+IFR-AK-CAZ-SC(4) 7,772.93 74.08 105.19 4,323.89 4,169.18 -542.54 5,008.93 5,926,838.56 1,605,956.47 1.42 4,991.39 MWD+IFR-AK-CAZ-SC(4) 7,867.45 74.11 106.30 4,349.79 4,195.08 -567.21 5,096.42 5,926,813.44 1,606,043.82 1.13 5,082.25 MWD+IFR-AK-CAZ-SC(4) 7,962.19 74.08 108.75 4,375.76 4,221.05 -594.64 5,183.29 5,926,785.55 1,606,130.54 2.49 5,173.18 MWD+IFR-AK-CAZ-SC(4) 8,056.39 74.19 109.40 4,401.51 4,246.80 -624.25 5,268.93 5,926,755.50 1,606,216.02 0.67 5,263.44 MWD+IFR-AK-CAZ-SC(4) 8,150.73 73.61 109.64 4,427.67 4,272.96 -654.54 5,354.36 5,926,724.77 1,606,301.28 0.66 5,353.66 MWD+IFR-AK-CAZ-SC(4) 8,244.95 73.69 110.01 4,454.20 4,299.49 -685.20 5,439.41 5,926,693.66 1,606,386.16 0.39 5,443.60 MWD+IFR-AK-CAZ-SC(4) 8,340.09 73.58 109.25 4,481.00 4,326.29 -715.87 5,525.39 5,926,662.55 1,606,471.97 0.78 5,534.44 MWD+IFR-AK-CAZ-SC(4) 8,434.93 73.58 109.73 4,507.81 4,353.10 -746.22 5,611.15 5,926,631.75 1,606,557.56 0.49 5,625.00 MWD+IFR-AK-CAZ-SC(4) 8,529.42 73.63 108.51 4,534.49 4,379.78 -775.91 5,696.79 5,926,601.62 1,606,643.04 1.24 5,715.28 MWD+IFR-AK-CAZSC(4) 8,623.95 73.61 108.73 4,561.14 4,406.43 -804.87 5,782.74 5,926,572.22 1,606,728.82 0.22 5,805.68 MWD+IFR-AK-CAZ-SC(4) 8,718.56 74.15 109.08 4,587.41 4,432.70 -834.32 5,868.73 5,926,542.32 1,606,814.65 0.67 5,896.24 MWD+IFR-AK-CAZ-SC(4) 8,813.60 74.17 109.08 4,613.35 4,458.64 -864.20 5,955.13 5,926,511.99 1,606,900.89 0.02 5,987.31 MWD+IFR-AK-CAZ-SC(4) 8,908.18 74.08 107.73 4,639.23 4,484.52 -892.93 6,041.45 5,926,482.81 1,606,987.05 1.38 6,078.01 MWD+IFR-AK-CAZ-SC(4) 5/7/2015 3:06:45PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9©154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,003.06 74.20 107.04 4,665.16 4,510.45 -920.20 6,128.55 5,926,455.09 1,607,073.99 0.71 6,169.12 MWD+IFR-AK-CAZ-SC(4) 9,097.82 74.12 105.89 4,691.02 4,536.31 -946.03 6,215.97 5,926,428.80 1,607,161.27 1.17 6,260.20 MWD+IFR-AK-CAZ-SC(4) 9,192.11 74.14 106.72 4,716.81 4,562.10 -971.50 6,303.02 5,926,402.89 1,607,248.18 0.85 6,350.82 MWD+IFR-AK-CAZ-SC(4) 9,287.37 74.03 107.00 4,742.93 4,588.22 -998.07 6,390.69 5,926,375.86 1,607,335.70 0.31 6,442.31 MWD+IFR-AK-CAZ-SC(4) 9,381.66 74.17 106.79 4,768.76 4,614.05 -1,024.42 6,477.46 5,926,349.06 1,607,422.32 0.26 6,532.88 MWD+I FR-AK-CAZ-SC(4) 9,476.49 74.14 106.76 4,794.65 4,639.94 -1,050.75 6,564.80 5,926,322.27 1,607,509.52 0.04 6,624.00 MWD+I FR-AK-CAZ-SC(4) 9,571.44 74.14 108.21 4,820.60 4,665.89 -1,078.19 6,651.92 5,926,294.38 1,607,596.48 1.47 6,715.16 MWD+I FR-AK-CAZ-SC(4) 9,666.22 74.08 107.78 4,846.55 4,691.84 -1,106.35 6,738.61 5,926,265.77 1,607,683.02 0.44 6,806.10 MWD+I FR-AK-CAZ-SC(4) 9,760.66 74.08 108.10 4,872.46 4,717.75 -1,134.33 6,825.02 5,926,237.35 1,607,769.26 0.33 6,896.70 MWD+I FR-AK-CAZ-SC(4) 9,855.63 74.14 107.42 4,898.46 4,743.75 -1,162.19 6,912.00 5,926,209.03 1,607,856.10 0.69 6,987.85 MWD+IFR-AK-CAZ-SC(4) 9,949.63 74.02 108.17 4,924.24 4,769.53 -1,189.81 6,998.07 5,926,180.96 1,607,942.01 0.78 7,078.04 MWD+IFR-AK-CAZ-SC(4) 10,044.46 74.05 107.26 4,950.33 4,795.62 -1,217.56 7,084.92 5,926,152.77 1,608,028.70 0.92 7,169.02 MWD+I FR-AK-CAZ-SC(4) 10,139.34 74.47 105.93 4,976.06 4,821.35 -1,243.64 7,172.44 5,926,126.23 1,608,116.07 1.42 7,260.25 MWD+IFR-AK-CAZ-SC(4) 10,233.24 75.06 105.16 5,000.74 4,846.03 -1,267.92 7,259.72 5,926,101.50 1,608,203.22 1.01 7,350.81 MWD+IFR-AK-CAZ-SC(4) 10,327.81 75.54 106.36 5,024.74 4,870.03 -1,292.76 7,347.76 5,926,076.20 1,608,291.12 1.33 7,442.24 MWD+IFR-AK-CAZSC(4) 10,422.74 77.50 106.27 5,046.87 4,892.16 -1,318.69 7,436.35 5,926,049.81 1,608,379.56 2.07 7,534.48 MWD+IFR-AK-CAZSC(4) 10,516.49 80.09 105.40 5,065.08 4,910.37 -1,343.78 7,524.81 5,926,024.26 1,608,467.89 2.91 7,626.39 MWD+IFR-AK-CAZSC(4) 10,611.75 80.49 104.69 5,081.15 4,926.44 -1,368.15 7,615.49 5,925,999.41 1,608,558.43 0.85 7,720.26 MWD+I FR-AK-CAZ-SC(4) 10,706.46 80.66 105.36 5,096.66 4,941.95 -1,392.37 7,705.73 5,925,974.72 1,608,648.53 0.72 7,813.68 MWD+IFR-AK-CAZ-SC(4) 10,801.55 80.06 105.18 5,112.58 4,957.87 -1,417.06 7,796.16 5,925,949.56 1,608,738.83 0.66 7,907.40 MWD+IFR-AK-CAZ-SC(4) 10,896.53 80.05 106.72 5,128.99 4,974.28 -1,442.77 7,886.11 5,925,923.39 1,608,828.63 1.60 8,000.90 MWD+IFR-AK-CAZ-SC(4) 10,990.82 79.03 107.30 5,146.10 4,991.39 -1,469.90 7,974.78 5,925,895.81 1,608,917.14 1.24 8,093.49 MWD+IFR-AK-CAZ-SC(4) 11,084.14 79.05 107.39 5,163.85 5,009.14 -1,497.21 8,062.23 5,925,868.04 1,609,004.44 0.10 8,184.95 MWD+IFR-AK-CAZ-SC(4) 11,179.03 79.05 107.82 5,181.87 5,027.16 -1,525.39 8,151.03 5,925,839.40 1,609,093.08 0.44 8,277.93 MWD+IFR-AK-CAZ-SC(4) 11,274.58 79.13 108.75 5,199.96 5,045.25 -1,554.82 8,240.11 5,925,809.50 1,609,182.00 0.96 8,371.49 MWD+I FR-AK-CAZ-SC(4) 11,369.07 79.10 108.92 5,217.80 5,063.09 -1,584.78 8,327.93 5,925,779.09 1,609,269.66 0.18 8,463.95 MWD+I FR-AK-CAZ-SC(4) 11,463.44 79.10 109.08 5,235.64 5,080.93 -1,614.95 8,415.55 5,925,748.47 1,609,357.11 0.17 8,556.27 MWD+I FR-AK-CAZ-SC(4) 11,557.78 79.19 108.17 5,253.41 5,098.70 -1,644.54 8,503.35 5,925,718.42 1,609,444.74 0.95 8,648.62 MWD+I FR-AK-CAZ-SC(4) 11,652.59 79.64 108.50 5,270.83 5,116.12 -1,673.86 8,591.82 5,925,688.64 1,609,533.05 0.59 8,741.55 MWD+I FR-AK-CAZ-SC(4) 11,748.14 79.57 108.75 5,288.07 5,133.36 -1,703.87 8,680.88 5,925,658.17 1,609,621.94 0.27 8,835.22 MWD+I FR-AK-CAZ-SC(4) 11,842.29 79.51 108.70 5,305.16 5,150.45 -1,733.59 8,768.56 5,925,627.99 1,609,709.46 0.08 8,927.49 MWD+I FR-AK-CAZ-SC(4) 11,936.81 79.57 110.94 5,322.32 5,167.61 -1,765.11 8,856.00 5,925,596.02 1,609,796.72 2.33 9,019.96 MWD+IFR-AK-CAZ-SC(4) 12,031.50 79.74 112.93 5,339.33 5,184.62 -1,799.90 8,942.40 5,925,560.78 1,609,882.93 2.08 9,112.21 MWD+IFR-AK-CAZ-SC(4) 12,126.71 79.98 115.56 5,356.09 5,201.38 -1,838.39 9,027.85 5,925,521.85 1,609,968.17 2.73 9,204.43 MWD+I FR-AK-CAZ-SC(4) 12,187.00 80.08 118.18 5,366.53 5,211.82 -1,865.22 9,080.81 5,925,494.74 1,610,020.99 4.28 9,262.31 MWD+IFR-AK-CAZ-SC(5) 7-5/8"x 9-7/8" 12,220.64 80.14 119.64 5,372.31 5,217.60 -1,881.24 9,109.82 5,925,478.57 1,610,049.91 4.28 9,294.33 MWD+IFR-AK-CAZ-SC(5) 12,270.43 81.20 122.55 5,380.39 5,225.68 -1,906.61 9,151.89 5,925,452.98 1,610,091.84 6.15 9,341.29 MWD+IFR-AK-CAZ-SC(5) 12,315.32 81.82 125.70 5,387.02 5,232.31 -1,931.52 9,188.64 5,925,427.89 1,610,128.45 7.08 9,382.97 MWD+IFR-AK-CAZ-SC(5) 12,368.00 81.76 129.46 5,394.54 5,239.83 -1,963.31 9,229.95 5,925,395.88 1,610,169.59 7.07 9,430.75 MWD+IFR-AK-CAZ-SC(5) 12,410.45 81.82 132.75 5,400.61 5,245.90 -1,990.93 9,261.60 5,925,368.10 1,610,201.10 7.67 9,468.14 MWD+IFR-AK-CAZ-SC(5) 12,462.71 81.75 136.63 5,408.08 5,253.37 -2,027.30 9,298.37 5,925,331.55 1,610,237.67 7.35 9,512.61 MWD+I FR-AK-CAZ-SC(5) 12,505.42 81.75 138.34 5,414.20 5,259.49 -2,058.45 9,326.93 5,925,300.25 1,610,266.07 3.96 9,547.87 MWD+I FR-AK-CAZ-SC(5) 12,561.12 81.89 139.57 5,422.13 5,267.42 -2,100.03 9,363.13 5,925,258.48 1,610,302.05 2.20 9,593.05 MWD+I FR-AK-CAZ-SC(5) 5/7/2015 3:06:45PM Page 5 COMPASS 5000.1 Build 65 4110 • Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-316 Project: Kuparuk River Unit TVD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Site: Kuparuk 2L Pad MD Reference: 39.81+114.9 @ 154.71 usft(Doyon25) Well: 2L-316 North Reference: True Wellbore: 2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 12,600.04 82.20 140.77 5,427.52 5,272.81 -2,129.63 9,387.82 5,925,228.76 1,610,326.58 3.16 9,624.17 MWD+IFR-AK-CAZ-SC(5) 12,695.01 83.59 144.09 5,439.27 5,284.56 -2,204.32 9,445.27 5,925,153.78 1,610,383.63 3.77 9,697.98 MWD+IFR-AK-CAZSC(5) 12,789.71 84.38 147.85 5,449.19 5,294.48 -2,282.36 9,497.96 5,925,075.47 1,610,435.91 4.04 9,767.98 MWD+IFR-AK-CAZ-SC(5) 12,884.18 84.68 150.81 5,458.20 5,303.49 -2,363.23 9,545.93 5,924,994.36 1,610,483.44 3.14 9,834.09 MWD+IFR-AK-CAZ-SC(5) 12,979.32 86.07 154.40 5,465.87 5,311.16 -2,447.41 9,589.55 5,924,909.96 1,610,526.62 4.03 9,896.78 MWD+IFR-AK-CAZ-SC(5) 13,075.10 87.61 157.90 5,471.16 5,316.45 -2,534.87 9,628.21 5,924,822.31 1,610,564.82 3.99 9,955.45 MWD+I FR-AK-CAZ-SC(5) 13,170.26 85.12 158.58 5,477.19 5,322.48 -2,623.06 9,663.41 5,924,733.94 1,610,599.56 2.71 10,010.94 MWD+I FR-AK-CAZ-SC(5) 13,265.22 84.54 160.19 5,485.75 5,331.04 -2,711.57 9,696.71 5,924,645.27 1,610,632.39 1.80 10,064.67 MWD+I FR-AK-CAZ-SC(5) 13,359.96 84.99 161.86 5,494.39 5,339.68 -2,800.79 9,727.38 5,924,555.90 1,610,662.60 1.82 10,116.01 MWD+I FR-AK-CAZ-SC(5) 13,454.46 86.46 164.80 5,501.44 5,346.73 -2,891.05 9,754.41 5,924,465.50 1,610,689.15 3.47 10,164.07 MWD+IFR-AK-CAZ-SC(5) 13,549.07 86.81 164.19 5,506.99 5,352.28 -2,982.06 9,779.66 5,924,374.37 1,610,713.92 0.74 10,210.59 MWD+IFR-AK-CAZ-SC(5) 13,644.37 88.20 162.78 5,511.14 5,356.43 -3,073.34 9,806.72 5,924,282.97 1,610,740.50 2.08 10,258.93 MWD+IFR-AK-CAZ-SC(5) 13,739.33 88.68 160.44 5,513.72 5,359.01 -3,163.41 9,836.67 5,924,192.75 1,610,769.97 2.51 10,309.78 MWD+IFR-AK-CAZ-SC(5) 13,833.72 88.56 158.34 5,516.00 5,361.29 -3,251.73 9,869.88 5,924,104.27 1,610,802.72 2.23 10,363.37 MWD+I FR-AK-CAZ-SC(5) 13,928.88 89.57 157.40 5,517.55 5,362.84 -3,339.86 9,905.73 5,924,015.95 1,610,838.10 1.45 10,419.47 MWD+I FR-AK-CAZ-SC(5) 14,023.98 91.07 152.03 5,517.02 5,362.31 -3,425.82 9,946.33 5,923,929.80 1,610,878.25 5.86 10,479.66 MWD+I FR-AK-CAZ-SC(5) 14,118.00 90.87 152.78 5,515.43 5,360.72 -3,509.13 9,989.87 5,923,846.27 1,610,921.35 0.83 10,542.07 MW D+I FR-AK-CAZ-SC(5) 14,212.79 90.60 156.23 5,514.21 5,359.50 -3,594.67 10,030.66 5,923,760.52 1,610,961.69 3.65 10,602.34 MWD+IFR-AK-CAZ-SC(5) 14,307.10 90.49 156.57 5,513.31 5,358.60 -3,681.09 10,068.42 5,923,673.92 1,610,998.99 0.38 10,659.88 MWD+IFR-AK-CAZ-SC(5) 14,402.56 89.52 157.16 5,513.31 5,358.60 -3,768.87 10,105.92 5,923,585.95 1,611,036.03 1.19 10,717.51 MWD+IFR-AK-CAZ-SC(5) 14,497.09 89.60 160.81 5,514.03 5,359.32 -3,857.10 10,139.82 5,923,497.56 1,611,069.46 3.86 10,771.74 MWD+IFR-AK-CAZ-SC(5) 14,592.25 89.05 162.79 5,515.15 5,360.44 -3,947.48 10,169.54 5,923,407.02 1,611,098.70 2.16 10,822.44 MWD+I FR-AK-CAZ-SC(5) 14,686.70 89.19 162.31 5,516.60 5,361.89 -4,037.58 10,197.85 5,923,316.79 1,611,126.55 0.53 10,871.71 MWD+I FR-AK-CAZ-SC(5) 14,781.82 89.43 160.62 5,517.75 5,363.04 -4,127.75 10,228.09 5,923,226.47 1,611,156.31 1.79 10,922.86 MWD+IFR-AK-CAZ-SC(5) 14,876.92 89.16 157.40 5,518.92 5,364.21 -4,216.52 10,262.15 5,923,137.53 1,611,189.90 3.40 10,977.39 MWD+I FR-AK-CAZ-SC(5) 14,930.00 88.53 156.63 5,519.99 5,365.28 -4,265.38 10,282.87 5,923,088.57 1,611,210.36 1.87 11,009.31 MWD+I FR-AK-CAZ-SC(5) 14,990 00 88.53 156.63 5,521 53 5,366.82 -4,320.44 10,306.66 5,923,033.39 1,611,233.87 0.00 11,045.72 PROJECTED to TD 4 1/2"x 6-3/4" 5/7/2015 3:06:45PM Page 6 COMPASS 5000.1 Build 65 OF T 0),, I//7;�s THE STATE Alaska Oil and Gas mw \\\'lei o f �T Conservation Commission 333 West Seventh Avenue x=`_ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �*hMain: 907.279.1433 OF ' Fax: 907.276.7542 ALAr�' www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-316 ConocoPhillips Alaska, Inc. Permit No: 215-006 Surface Location: 188' FNL, 734' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 4536' FNL, 990' FEL, SEC. 24, T1ON, R7E, 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, Daniel T. Seamount, Jr. Commissioner DATED this1! day of February, 2015. • � , RECEIVED r • STATE OF ALASKA JAN 1 4 Z015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1a.Type of Work: 1 b.Proposed Well Class: -Development-Oil Q Service-Winj ❑ . Single Zone El 1c.Specify if well is proposed for: Drill • Q Lateral ❑ Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry E Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: '5. Bond: U Blanket. u Single Well 11.Well Name and Number: tz ConocoPhillips Alaska, Inc. • Bond No. 59-52-180 - KRU 2L-316 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 14990' • TVD: 5509' . Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 188'FNL,734'FEL,Sec.22,T1ON,R7E, UM • ADL 380052,380051 i Tarn Oil Pool " Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2236'FNL,2025'FEL,Sec.24,T1ON, R7E, UM 4600,4599 3/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 4536'FNL,990'FEL,Sec.24,T1ON, R7E, UM 5120 b Nearest Property: 1.25 miles to KRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 157 feet 15.Distance to Nearest Well Open Surface:x- 460917 y- 5927658 Zone- 4 • GL Elevation above MSL: 1 l3- 39eet to Same Pool: 2L-311 ,11851 16.Deviated wells: Kickoff depth: .400 ft. 17.Maximum AntiriAated Pressures in psig(see 20 MC 25.035) engi G r)i<6 Maximum Hole Angle: . 91° deg Downhole:2249 psig Surface: psig l 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 20" 16" 62.5# HW Welded 80' 40' 40' 120' 120' r drive-7) VTL 13.5" 10.75" 45.5# L-80 Hydril 563 2470' 40' 40' 2510' 2402' 10 0 sx LiteCRETE, 1 sx LiteCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 11797' 40' 40' 11837' 5497' 9.875" 7.625" 39# TN-110 Hydril 563 300' 11837' 5497' 12137' 5356' 1200 sx Class"G" 6.5" 4.5" 12.6# L-80 Hydril 521 312' 11987' 5332' 12299' 5383' 6.5" 4.5" 12.6# L-80 IBTM 2691' 12299' 5383 14990' 5508' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: S.11S 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Email Steve.Shultzacontractor.cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager SignatureA a Phone:265-6120 Date �'��Z°t Commission Use Only Permit to Drill API Number: Permit Approval I See cover letter Number: 3.!$- 00(0 50- 103 - c) (:).7--()L1c) (:).7--()L1 ��� L,/-00 -00 I Date: ,�/ I't for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales: 0i Other:54 P tes i. to 3600�S, Samples req'd: Yes ❑ No J Mud log req'd: YrJ Nqr )4hhfJ/av 7reV�,.2,h-r 17-3-17-3-7"- H2Smeasures: Yes IMI ❑, , Directionalsvyreq'd: Yes Non_ f'D -d Z 5o /..75 , Spacing exception req'd: Yes ❑ No Lii Inclination-only svy req'd: Yes No rum PR VED BY THE a m J 1 1 Ls Approved by: cart, a la'h. It 1 n` iL.g Date: Form 10-401(Revised 10/2012) This permi ' a t r date of approval(20 AAC 25.005(g)) r i''Zf'IS� VTL- z/5//5- Ink a-ii- �= .� . CorlOPost Office Box 100360 C iIIi PS Anchorage,Alaska 99510-0360 Phone(907)263-4864 Email: steve.shultz(a,contractor.conocophiilips.com RECEIVED January 15, 2015 Alaska Oil and Gas Conservation Commission JAN 14 2015 333 West 7`h Avenue, Suite 100 Anchorage,Alaska 99501 ^ GCC Re: Application for Permit to Drill 2L-316 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2L-316 from the Tarn 2L drilling pad. This well is intended to be a producing well from the Bermuda horizon. The intended spud date for this well is March 1st,2015 using Doyon 25. When the Doyon 25 rig moves onto 2L-316,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor, spud the well with a 13W bit,drill to the surface casing point,then run and cement the 10%"45.5#L-80 Hydril 563 surface casing in place. A 9%" bit will be made up and the surface casing drilled out. The well will then be drilled down to the intermediate casing point(topsetting the Bermuda)where a string of 7%"29.7#L-80 Hydril 563 casing will be run and cemented in place.A 6W bit will be run to drill out the intermediate 7%"casing and drilled ahead to the total depth of the well. Finally, a 4%" production liner with swell packers and frac sleeves will be slid in position for future frac operations. Please find attached the information required by 20 ACC 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 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Diverter Placement and Orientation 7. Directional drilling/collision avoidance information as required by 20 ACC 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 ACC 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 Steve Shultz at 263-4297. Sincere , S -ve Shultz Drilling Engineer Attachments • JOation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 2L-316 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 6 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 7 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 8 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 (Requirements of 20 AAC 25.005 (c)(14)) 9 2L-316 APD Page 1 of 14 Printed:5-Feb-15 •ation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 15. Attachment Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Placement and Orientation 2L-316 APD Page 2 of 14 Printed:5-Feb-15 • fleation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 1. Well Name (Requirements of 20 AAC 25.005(0) The well for which this application is submitted will be designated as 2L-316. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. The rig will drill a 13-1/2"surface hole and case with 10-3/4" L-80 with premium connections. The 9-7/8" intermediate section will be drilled to +/- 150' MD above the Bermuda sand, and 7-5/8"top-set casing will be run. A 6-1/2" horizontal production hole will be drilled to TD. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion. Finally, a 3-1/2"gaslifted tubing assembly will be run for the upper completion. 15--7 Location at Surface 188.0' FNL, 733.7' FEL, Sec 22, T1ON, R7E, UM , NAD 1927 RKB Elevation 1,42-."9'AMSL Northings: 5,927,657.89 Eastings: 460,917.18 Pad Elevation '114.9'AMSL Location at 7 5/8" Intermediate Csg Pt. 2,053.1' FNL, 2,271.1' FEL, Sec 14, T1ON, R7E, UM Nad 1927 Measured Depth, RKB: 12,137' Northings: 5,925,567.46 Eastings:469,931.93 Total Vertical Depth, RKB: 5,356' Total Vertical Depth, SS: 5,203' Location at Top of Productive 2,236.4' FNL, 2025.4' FEL, Sec 24, T1ON, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 12,448' Northings: 5,925,567.46 Eastings:470,176.92 Total Vertical Depth, RKB: 5,406' Total Vertical Depth, SS: 5,249' Location at Total Depth 4,536.4' FNL, 990.4' FEL, Sec 24, T1ON, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 14,990' Northings: 5,923,263,68 Eastings: 471,203.34 Total Vertical Depth, RKB: 5,509' Total Vertical Depth, SS: 5,351' 2L-316 APD Page 3 of 14 Printed:5-Feb-15 • 1 ation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Hole Size Csg Setting Fracture Pore Casing Size below Casing Depth Gradient pressure ASP (in) Shoe MD/TVD(ft) (lbs. /gal) (psi) Drilling (psi) 16 13 '/2' 120/ 120 10.9 68 56 10-3/4 9%" 2,509/2,402 14.5 2,500 1,571 6 '/2" 12,137/ 5,356 15 2,800 2,249 • NOTE: The Doyon 25, 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)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—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal (EMW X TVD) • Equivalent Mud Wt(EMW)- LOT from offset wells 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG)—0.1] D = [(10.9 X(.052))—0.1]x 120' = 56 psi OR ASP = FPP—(0.1 x D) =1,112—(0.1 x 2,402') = 872 psi 2L-316 APD Page 4 of 14 Printed:5-Feb-15 > ation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 2. Drilling below surface casing (10-3/4") ASP = [(FG)—0.1] D = [(14.5 X(.052))—0.1]x 2,402' = 1,571 psi OR ASP = FPP—(0.1 x D) =2,500—(0.1 x 5,220') = 1,978 psi 3. Drilling below intermediate casing (7-5/8") ASP= [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1]x 5,356' = 3,642 psi OR ASP = FPP—(0.1 x D) =2,800—(0.1 x 5,508') = 2,249 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; The most recent SBHPs from offset wells producing wells are: 2L-312: 2,356 psig; 2L-307: 2,650 psig; 2L-306: 1,156 psig; 2L-311: 1,864 psig; The most recent SBHPs for the offset injection wells are: 2L-310: 1,534 psig; and 2L-305: 4,314 psig. Prior to drilling well 2L-316, further offset well pressure surveillance will occur and offset injectors may be shut-in to manage pattern pressures. The Tarn reservoir model predicts the 2L-316 will find reservoir pressure at or near original reservoir pressure of 2,000 to 2,400 psig at the heel of the well with the potential for higher or lower pressure as it is drilled closer to the higher pressured offset injectors and depleted producers. The upper limit of reservoir pressure is estimated at 2,800 psig, but continued pressure monitoring will occur prior to spudding well 2L-316. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 2L-316 APD Page 5 of 14 Printed:5-Feb-15 • A•tion for Permit to Drill,Well 2L-316 Saved:5-Feb-15 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 21-316 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Grade Conn. Length MD/TVD MD/TVD Cement Program OD(in) (in) (lb/ft) (ft) (ft) (ft) 16 20" 62.5# HW Welded 80' Surf 120'/120' Existing Hydril Planned:Cement to Surface with 10%" 131/2" 45.5# L-80 563 2,470' Surf 2,510'/2,402' sx LiteCRETE 11ppg& sx 12 ppg LiteCRETE H dril 7%" 9%" 29.7# L-80 563 11,798' Surf 11,837'/5,304' Planned:Cement Top planned @ 7,537' MD with sx 15.8 ppg Class G 7%" 9%" 39# TN11OSS 563'l 300' 11,837' 12,137'/5,356' 4%x" 6%:" 12.6# L-80 Hydril 312' 11,987' 12,299'/5,383' 521 Liner Hanger 41A" 6%" 12.6# L-80 IBTM 2,691' 12,299' 14,990'/5,508' Swell packers&frac sleeves 4%" 12.6# L-80 IBTM ^'30' Surf "'30'/30' top 1 jt of tubing 3%:" 9.3# L-80 EUE8RM "11,987' -30' 11,987' Tubing with Premier Packer Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 7-5/8" 39 TN- 3 Hyd563 10,370 psi 8,296 psi 11,480 psi 9,184 psi 110 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 25. 2L-316 APD Page 6 of 14 Printed:5-Feb-15 • ,ation for Permit to Drill,Well 2L-316 Saved:5-Feb-15 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.5- 10 ppg 9.6— 10.0 ppg 10.0- 11.0 ppg YP 60-80 18-28 18 -28 Funnel Viscosity (sec) 75—250 40-55 45 -55 PV 20-60 20-25 20-25 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water / gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.5 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight above 9.5 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. Production Hole Section: KLASHIELD water-based polymer mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A-Application is not for an offshore well. 2L-316 APD Page 7 of 14 Printed:5-Feb-15 Action for Permit to Drill,Well 2L-316 Saved:5-Feb-15 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 25 on 2L-316 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface casing point(2,510' MD/2,402' TVD) according to the directional plan. Run MWD/ LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling)and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5#L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole to 12,137' MD/5,356'TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5"drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to 12,137' MD/5,356' ND and cement in place with a minimum of 500' of cement above the Iceberg formation. 13. MU 6-1/2" bit and BHA, RIH on 4" drill pipe. 14. Drill the 6-1/2" production hole to 14,990' MD/5,508' ND as per directional program. 15. POOH, and run 4 '/2" production liner complete with swell packers and frac sleeves. 16. Place liner hanger on depth, pressure up and set hanger, continue to pressure up and release liner hanger from running tool, POOH with running tool while laying down drill pipe. 17. Run 3-1/2"completion tubing with premier packer and seals and set packer at+/- 12,000' MD/5,333' ND. 18. Bleed of pressure in tubing and pressure up annulus to shear out lower GLM 19. Change well over to KW brine, install BPV 20. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 2L-316 APD Page 8 of 14 Printed:5-Feb-15 • Apetion for Permit to Drill,Well 2L-316 Saved:5-Feb-15 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Placement and Orientation 2L-316 APD Page 9 of 14 Printed:5-Feb-15 • S I. 1 \ ' t- s. 10'. 20�; ! :s22 Iiiti'5 _ >-,.; eg x ''. s '. o rL �' J.- ..,-,A. 01 , -s''' ..r. ,',, f,' - N - cy-1 ----7.---, ._-_. , \.,.-, , . , ....,.. 1,.., . . .0, .. . .i..,....,, ,,,..;,,,,....,:,„,4 ._ I , f \ : ' :2\ fp� ..- (V =a N . t LQ',,, • . 31a J v� 1 3 ,, v52�1 •r, ., 1 .. '*4 '' .-,,,,,,,.. 44, ., „,., -r.,.. , te... r.r.i- �•,.= • 2 L-31 6wp06.1 6.847 Plan Summary SURVEY PROGRAM I pth From Depth To Survey/Plan Tool "" 39.50 1000.00 2L-316wp06.1 (Plan:2L-316) GYD-GC-SS 1000.00 2500.00 2L-316wp06.1 (Plan:2L-316) MWD 1000.00 1000.00 2500.00 2L-316wp06.1 (Plan: 2L-316) MWD+IFR-AK-CAZ-SC pr:„2500.00 3500.00 2L-316wp06.1 (Plan: 2L-316)2500.00 12137.16 2L-316wp06.1 (Plan: 2L-316) MWD+IFR-AK-CAZ-SC12137.16 13200.00 2L-316wp06.1 (Plan:2L-316) MWD12137.16 14989.51 2L-316wp06.1 (Plan:2L-316) MWD+IFR-AK-CAZ-SC , \ A, A IP 4 OS . : CASING DETAILS / ��QTVD MD Name Size � 2401.50 2509.63 10-3/4" x 13-1/2" 10-3/4 5356.49 12137.16 7-5/8"x 9-7/8" 7-5/8 41111111", iii .. 5507.60 14989.51 3-1/2"x 6" 3-1/2 ry '' 7-5/8"x 9-7/8" Top Bermuda j0- I'°x 13-1/2" Top Berm Seis >5- Pfrost CAMP-SST T-3.1 _5 1000 C-80 , - -- _ 11 -....'.\ ! _10-3/4"x 13-1/2" c iiii °in ' 3-1/2"x 6" N m o 0 _ I -... 0-40.... I _ An o 0 0 0 0 7-5/8"x 9-7/8" 3-1/2"x 6" oI _ _ C-37 _I _ „,,..c.% 0 0 o o co-0 0� 0o C 50 T-7m o Z 11 0 2 .2,° 0 0 Lo I I I 1 I 1 � I I 1 I ' I I ( I 0 3500 7000 10500 14000 0 2000 4000 6000 8000 10000 120` 0 Measured Depth Horizontal Departure g 0 ill I I ISI f ............. .... III'.I I I ill:.. 330 30 ill II IIIlllld`E kX �e1 ° _- .. I ryI 60 ,n yy J11 300 . 1aLa. 1'11111 V ».60 oao - CD CI) 4 s00 2200 4E' I 270 .,90 , ono _ _ U30 .( i�� • tri/P ;o In .i.:-.,-;,,,;,,,,,,-, . N• _ • 3 61m . Illi __. -. 240 3 rr, ��� • 4` ,,3 MOO - t . 2L.3 y �� 00 o I I I I I I I 1 I I I I I I I I I I I I I 1 I 210 �Vfi 1.*r\q". r'.2..1.5 '.3.1.5 i2000 - .000 0 2000 4000 6000 8000 10000 12000 14000 ' ."" „.o - .00 180 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 311.50 0.00 0.00 311.50 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 561.50 3.75 355.00 561.32 8.15 -0.71 1.50 355.00 -2.66 Start DLS 1.50 TFO 10.00 4 861.50 8.22 0.47 859.61 39.38 -1.39 1.50 10.00 -10.88 Start DLS 2.00 TFO 10.00 5 1411.50 19.15 6.27 1393.22 168.74 8.81 2.00 10.00 -32.28 Start 100.00 hold at 1411.50 MD 6 1511.50 19.15 6.27 1487.68 201.35 12.39 0.00 0.00 -36.69 Start DLS 3.51 TFO 107.10 7 2509.63 34.00 85.00 2401.50 394.42 317.83 3.51 107.10 212.97 Start 20.00 hold at 2509.63 MD 8 2529.63 34.00 85.00 2418.08 395.40 328.97 0.00 0.00 223.54 Start DLS 3.00 TFO 25.00 9 3011.50 47.45 93.23 2782.70 397.14 642.06 3.00 25.00 526.91 Start DLS 2.54 TFO 14.45 10 4072.92 73.77 100.00 3299.50 284.51 1551.02 2.54 14.45 1436.12 Start 1700.00 hold at 4072.92 MD 1 1 5772.92 73.77 100.00 3774.64 1.07 3158.48 0.00 0.00 3064.40 Start DLS 2.07 TFO 89.22 12 6120.44 74.00 107.50 3871.23 -78.23 3482.50 2.07 89.22 3397.98 Start 4137.22 hold at 6120.44 MD 1310257.66 74.00 107.50 5011.60 -1274.12 7275.39 0.00 0.00 7367.52 Start DLS 4.30 TFO-0.51 1410386.92 79.56 107.45 5041.15 -1311.89 7395.37 4.30 -0.51 7493.07 Start Turn 0.00 1511838.67 79.56 107.45 5304.21 -1740.03 8757.38 0.00 0.00 8918.20 Start DLS 4.29 TFO 87.62 T-3.1 1612137.16 80.35 120.44 5356.49 -1859.08 9025.37 4.29 87.62 9207.03 Start 20.00 hold at 12137.16 MD 1712157.16 80.35 120.44 5359.85 -1869.07 9042.37 0.00 0.00 9225.94 Start DLS 4.51 TFO 85.38 1812958.71 84.93 156.63 5466.03 -2455.28 9558.63 4.51 85.38 9868.68 Start 29.08 hold at 12958.71 MD 1912987.79 84.93 156.63 5468.60 -2481.87 9570.12 0.00 0.00 9886.27 2L-316 Heel 23Sep14 EB Start DLS 3.00 TFO 50.40 2013135.74 87.76 160.05 5478.04 -2619.05 9624.60 3.00 50.40 9972.32 Start 77.40 hold at 13135.74 MD 21 13213.14 87.76 160.05 5481.06 -2691.75 9651.00 0.00 0.0010015.51 Start DLS 3.00 TFO-83.40 2213281.83 88.00 158.00 5483.60 -2755.85 9675.57 3.00 -83.4010054.86 2L-316 T2 23Sep14 EB Start DLS 2.00 TFO-26.65 2313318.32 88.65 157.67 5484.67 -2789.62 9689.33 2.00 -26.6510076.38 Start 1171.36 hold at 13318.32 MD 2414489.68 88.65 157.67 5512.22 -3872.87 10134.20 0.00 0.0010770.11 Start DLS 2.00 TFO 55.05 2514607.27 90.00 159.60 5513.60 -3982.36 10177.03 2.00 55.0510838.15 2L-316 T3 23Sep14 EB Start DLS 2.00 TFO 3.39 2614655.34 90.96 159.66 5513.20 -4027.43 10193.77 2.00 3.3910865.29 Start 334.17 hold at 14655.34 MD 2714989.51 90.96 159.66 5507.60 -4340.71 10309.92 0.00 0.0011053.79 2L-316 Toe 23Sep14 EB TD at 14989.51 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 TM Depth Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Magnetic Model Date: 01-Jan-15A System(SS)Reference: Mean Sea Level a MagneticMagnetic Recreation: a True North /Y: 5927407.11 y To convert a Direction to a True Direction,Add 18.79°East Ground Level/Mud Line: 117.106 East/X: 1600950.92 Rig: Doyon 25 Error creating XSL parser for script. The oaramPter is incorrect URLUINAL • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-316 -Slot 2L-316* Plan: 2L-316 Plan: 2L-316wp06.1 Plan Summary 05 November,2014 ConocoPhillips U IGINAL ill • Schlumberger N.-- Plan Summary ConocoPhillips Company:. ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316' Project:. Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North.Reference: True Wettbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2L Pad Site Position: Northing: 5,927,44435 usft Latitude: 70'12'47.137 N From: Map Easting: 1,601,111.65 usft Longitude: 150°19'1.199 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.30' Welt Plan:2L-316-Slot 2L-316' Well Position +N/-S 0.00 usft Northing: 5,927,407.11 usft Latitude: 70°12 46.763 N +E/-W 0.00 usft Easting: 1,600,950.92 usft Longitude: 150°19'5.860 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.10usft Wellbore Plan:2L-316 Magnetics Model Name Sample Date Declination Dip Angie Field Strength (°1 (') (nT) BGGM2014 1/1/2015 18.79 80.78 57,549 Design 2L-316wp06.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: :' Depth From(TVD) +N/-S 4.E1-W Direction '� -,l', s� (usft) (usft) (usft) (°) �° 39.50 0.00 0.00 104.00 11/5/2014 2:17.16PM Page 2 COMPASS 5000.1 Build 65 OflGINAL ! • 2L-316wp06 Plan View 1 10-3/4"x 13-1/2" 1500- 0 o 0 co d' O O ,11 0 O 66 (0 o 0 nO 00 O 0 o O S 0) co ;5.? 0 mO �I 500— v:1/ 0 7-5/8"x 9-7/8" ,300 -3000— 2L-316 Heel 23Sep14 EB" - O 2�3Ag.,..- 0 2L-316 T2 23Sep14 EB -4500— 2L-316 T3 23Sep14 EB - 2L-316 Toe 23Sep14 EB 3-1/2"x 6" -6000— I -1500 0 1500 3000 4500 6000 7500 9000 10500 12000 West(-)/East(+) (1500 usft/in) ORIGINAL • • • 2L-316wp06 Section View -1500- g 0- 0° c 1000 5 1500- o 200° o in \\3p° 00 O a °' ° 0 p 3000- co v v o -0310-3/4"x 13-1/2" o co O V o a ,�`� 0 0 0 2L-316wp06 0 H 4500- 0 0 0 ° 0 0 ^ Nco O O O O O , ?O q — tD J Oo 6000- 7-5/8"x 9-7/8" 3-1/2"x 6" 7500 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 104.00°(1500 usft/in) 0 IGINAL S . • 0 , 2L-316wp06 Section View A " 0_ 0° 1000- -/000 C S in =2000- 2000 0 10-3/4"x 13-1/2" o o 1 v,•39,°_----- ,- 03000- o Ta a c_) ,O, a .:,) > 0 co 0 . 0 7-5/8,"x 9-7/8" 1-.4000- ,N 0 2L-316wp06 N 0 0 0 0 , 0) 0 0 *-- o o, o o 5000- co o,Y. 53 o •-• Cr) . CO 3-1/2"x6' i 1 1 1 i I I 1 1 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Section at 158.00°(1000 usft/in) oRIGRAL • • 2L-316wp06 Section View 4600- 4800- 4 S 17) 5000- 0 0 N 7-5/8"x 9-7/8" o 5200— T-4.1 0 0 2L-316wp06 T-3.t_ c o 5400 ct o ° 71-- O A co Top Bermuda 5600 Top Berm Seis 3-1/2"x 6" 1 I 1 1 I 1 1 1 I 1 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 Vertical Section at 158.00°(450 usftlin) ORIGINAL ! • Schlumberger d.- Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate.Reference: Wet Plan:2L-316-Slot 2L-316* Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Survey Tool Program Date 11/5/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,000.00 2L-316wp06.1(Plan:2L-316) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,500.00 2L-316wp06.1(Plan:2L-316) MWD MWD-Standard 1,000.00 2,500.00 2L-316wp06.1(Plan:2L-316) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,500.00 3,500.00 2L-316wp06.1(Plan:2L-316) MWD MWD-Standard 2,500.00 12,137.16 2L-316wp06.1(Plan:2L-316) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12,137.16 13,200.00 2L-316wp06.1(Plan:2L-316) MWD MWD-Standard 12,137.16 14,989.51 2L-316wp06.1(Plan:2L-316) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting -tat.Error Vert.Error (usft) O (°) (usft) (usft). ("(100usft) r) (usft) (usft). (usft) (usft) 39.50 0.00 0.00 39.50 -117.10 0.00 0.00 5,927,407.11 1,600,950.92 0.00 0.00 100.00 0.00 0.00 100.00 -56.60 0.00 0.00 5,927,407.11 1,600,950.92 0.04 1.15 200.00 0.00 0.00 200.00 43.40 0.00 0.00 5,927,407.11 1,600,950.92 0.19 1.15 300.00 0.00 0.00 300.00 143.40 0.00 0.00 5,927,407.11 1,600,950.92 0.33 1.15 311.50 0.00 0.00 311.50 154.90 0.00 0.00 5,927,407.11 1,600,950.92 0.35 1.15 Start Build 1.50 400.00 1.33 355.00 399.99 243.39 1.50 355.00 5,927,408.13 1,600,950.84 0.48 1.15 500.00 2.83 355.00 499.92 343.32 1.50 0.00 5,927,411.74 1,600,950.54 0.62 1.15 561.50 3.75 355.00 561.32 404.72 1.50 0.00 5,927,415.26 1,600,950.25 0.71 1.15 Start DLS 1.50 TFO 10.00 600.00 4.32 356.33 599.73 443.13 1.50 10.00 5,927,417.96 1,600,950.06 0.77 1.15 700.00 5.81 358.57 699.33 542.73 1.50 8.67 5,927,426.78 1,600,949.74 0.92 1.16 800.00 7.30 359.89 798.68 642.08 1.50 6.44 5,927,438.19 1,600,949.66 1.07 1.16 861.50 8.22 0.47 859.61 703.01 1.50 5.13 5,927,446.49 1,600,949.73 1.17 1.16 Start DLS 2.00 TFO 10.00 900.00 8.98 1.33 897.68 741.08 2.00 10.00 5,927,452.25 1,600,949.86 1.23 1.16 1,000.00 10.96 3.00 996.17 839.57 2.00 9.15 5,927,469.53 1,600,950.62 1.40 1.16 1,100.00 12.94 4.17 1,093.99 937.39 2.00 7.50 5,927,490.19 1,600,952.04 1.50 1.16 11/512014 2:17:16PM Page 3 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger 0.,. Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316' Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60uvs(Doyon 25) Site: Kuparuk 2L Pad MD Reference:- plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD. TVDSS DLeg TFace Northing Easting Lat.Error Veil.Error (usft) (°( (°( (usft) (usft) (°ltoousft) (1 (usft) (usft) (usft) (usft) 1,200.00 14.93 5.03 1,191.05 1,034.45 2.00 6.36 5,927,514.18 1,600,954.11 1.58 1.16 1,300.00 16.92 5.69 1,287.20 1,130.60 2.00 5.53 5,927,541.48 1,600,956.82 1.76 1.15 1,400.00 18.92 6.21 1,382.35 1,225.75 2.00 4.89 5,927,572.06 1,600,960.18 2.04 1.15 1,407.67 19.07 6.25 1,389.60 1,233.00 2.00 4.39 5,927,574.54 1,600,960.46 2.08 1.15 Pfrost 1,411.50 19.15 6.27 1,393.22 1,236.62 2.00 4.36 5,927,575.79 1,600,960.61 2.08 1.15 Start 100.00 hold at 1411.50 MD 1,500.00 19.15 6.27 1,476.82 1,320.22 0.00 0.00 5,927,604.62 1,600,963.93 2.40 1.16 1,511.50 19.15 6.27 1,487.68 1,331.08 0.00 0.00 5,927,608.37 1,600,964.36 2.44 1.16 Start DLS 3.51 TFO 107.10 1,600.00 18.46 15.67 1,571.48 1,414.88 3.51 107.10 5,927,636.27 1,600,969.87 2.71 1.18 1,700.00 18.29 26.80 1,666.41 1,509.81 3.51 98.19 5,927,665.46 1,600,981.38 2.92 1.20 1,800.00 18.75 37.77 1,761.26 1,604.66 3.51 87.63 5,927,692.09 1,600,998.44 3.09 1.22 1,900.00 19.81 47.91 1,855.68 1,699.08 3.51 77.23 5,927,716.04 1,601,020.99 3.26 1.24 2,000.00 21.38 56.84 1,949.31 1,792.71 3.51 67.65 5,927,737.23 1,601,048.95 3.45 1.26 2,100.00 23.36 64.46 2,041.79 1,885.19 3.51 59.29 5,927,755.58 1,601,082.20 3.70 1.28 2,200.00 25.65 70.88 2,132.79 1,976.19 3.51 52.24 5,927,771.03 1,601,120.63 4.02 1.30 2,300.00 28.18 76.26 2,221.97 2,065.37 3.51 46.40 5,927,783.50 1,601,164.09 4.43 1.33 2,400.00 30.88 80.80 2,308.98 2,152.38 3.51 41.60 5,927,792.96 1,601,212.42 4.94 1.37 2,500.00 33.72 84.66 2,393.51 2,236.91 3.51 37.65 5,927,799.37 1,601,265.43 3.09 1.25 2,509.63 34.00 85.00 2,401.50 2,244.90 3.51 34.38 5,927,799.83 1,601,270.78 2.93 1.24 Start 20.00 hold at 2509.63 MD-10-314"x 13-112" 2,529.63 34.00 85.00 2,418.08 2,261.48 0.00 0.00 5,927,800.74 1,601,281.92 3.01 1.23 Start DLS 3.00 TFO 25.00 2,600.00 35.92 86.52 2,475.75 2,319.15 3.00 25.00 5,927,803.50 1,601,322.14 3.35 1.24 2,618.39 36.43 86.89 2,490.60 2,334.00 3.00 23.75 5,927,804.07 1,601,332.99 4.03 1.26 C-80 11/52014 2:17:16PM Page 4 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger ,1,.- Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316' Project Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60us0(Doyon 25) Site: Kuparuk 2L Pad - MD Reference: plan:39.5+117.1 @ 156.60usf(Doyon 25) Well - Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc. Azi(azimuth) TVD. TVDSS Oleg TFace Northing Easting. Lat.Error Vert.Error (usft) ('i (°l (usft) (nett). (°t100usft) ("I (usft) (usft) (usft) (usft) 2,687.61 3834 88.23 2,545.60 2,389.00 3.00 23.45 5,927,805.63 1,601,374.98 4.03 1.26 CAMP-SST 2,700.00 38.69 88.45 2,555.29 2,398.69 3.00 22.39 5,927,805.81 1,601,382.69 4.03 1.26 2,800.00 41.48 90.17 2,631.80 2,475.20 3.00 22.22 5,927,806.22 1,601,447.05 4.89 129 2,900.00 44.29 91.70 2,705.07 2,548.47 3.00 20.91 5,927,804.74 1,601,515.07 5.88 1.36 3,000.00 47.12 93.08 2,774.90 2,618.30 3.00 19.78 5,927,801.36 1,601,586.55 6.98 1.45 3,011.50 47.45 93.23 2,782.70 2,626.10 3.00 18.81 5,927,800.85 1,601,594.98 7.11 1.45 Start DLS 2.54 TFO 14.45 3,100.00 49.63 93.97 2,841.30 2,684.70 2.54 14.45 5,927,796.33 1,601,661.13 8.18 1.57 3,200.00 52.09 94.75 2,904.42 2,747.82 2.54 13.96 5,927,790.02 1,601,738.42 9.46 1.73 3,300.00 54.56 95.47 2,964.14 2,807.54 2.54 13.47 5,927,782.45 1,601,818.26 10.80 1.91 3,400.00 57.04 96.16 3,020.34 2,863.74 2.54 13.04 5,927,773.64 1,601,900.48 12.19 2.12 3,500.00 59.52 96.80 3,072.91 2,916.31 2.54 12.66 5,927,763.60 1,601,984.93 13.63 2.35 3,600.00 62.00 97.41 3,121.75 2,965.15 2.54 12.32 5,927,752.34 1,602,071.45 6.69 1.67 3,700.00 64.49 98.00 3,166.77 3,010.17 2.54 12.02 5,927,739.90 1,602,159.85 7.22 1.78 3,800.00 66.97 98.56 3,207.87 3,051.27 2.54 11.75 5,927,726.30 1,602,249.98 7.76 1.90 3,900.00 69.46 99.10 3,244.98 3,088.38 2.54 11.52 5,927,711.56 1,602,341.64 8.31 2.03 4,000.00 71.95 99.63 3,278.01 3,121.41 2.54 11.32 5,927,695.72 1,602,434.67 8.85 2.16 4,072.92 73.77 100.00 3,299.50 3,142.90 2.54 11.15 5,927,683.48 1,602,503.26 9.25 2.27 Start 1700.00 hold at 4072.92 MD 4,100.00 73.77 100.00 3,307.07 3,150.47 0.00 0.00 5,927,678.83 1,602,528.84 9.39 2.30 4,200.00 73.77 100.00 3,335.02 3,178.42 0.00 0.00 5,927,661.67 1,602,623.30 9.94 2.46 4,300.00 73.77 100.00 3,362.97 3,206.37 0.00 0.00 5,927,644.50 1,602,717.76 10.49 2.61 4,400.00 73.77 100.00 3,390.92 3,234.32 0.00 0.00 5,927,627.34 1,602,812.21 11.05 2.76 4,500.00 73.77 100.00 3,418.87 3,262.27 0.00 0.00 5,927,610.17 1,602,906.67 11.61 2.92 4,600.00 73.77 100.00 3,446.82 3,290.22 0.00 0.00 5,927,593.01 1,603,001.13 12.17 3.08 4,700.00 73.77 100.00 3,474.77 3,318.17 0.00 0.00 5,927,575.84 1,603,095.59 12.74 3.24 11/5/2014 2:17:16PM Page 5 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger `- Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316" Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (1 (°) (usft) (usft) (1/100usft) P1 (usft) (usft) (usft) (usft) 4,800.00 73.77 100.00 3,502.72 3,346.12 0.00 0.00 5,927,558.68 1,603,190.05 13.31 3.40 4,900.00 73.77 100.00 3,530.66 3,374.06 0.00 0.00 5,927,541.51 1,603,284.51 13.88 3.56 5,000.00 73.77 100.00 3558.61 3,402.01 0.00 0.00 5,927,524.35 1,603,378.96 14.45 3.72 5,100.00 73.77 100.00 3,586.56 3,429.96 0.00 0.00 5,927,507.18 1503,473.42 15.02 3.89 5,200.00 73.77 100.00 3,614.51 3,457.91 0.00 0.00 5,927,490.02 1,603,567.88 15.60 4.05 5,300.00 73.77 100.00 3,642.46 3,485.86 0.00 0.00 5,927,472.85 1,603,662.34 16.17 4.21 5,400.00 73.77 100.00 3,670.41 3,513.81 0.00 0.00 5,927,455.69 1,603,756.80 16.75 4.38 5500.00 73.77 100.00 3,698.36 3,541.76 0.00 0.00 5,927,438.52 1,603,851.26 17.33 4.54 5,600.00 73.77 100.00 3,726.31 3,569.71 0.00 0.00 5,927,421.36 1,603,945.71 17.91 4.70 5,683.33 73.77 100.00 3,749.60 3,593.00 0.00 0.00 5,927,407.05 1,604,024.42 18.49 4.87 CSO 5,700.00 73.77 100.00 3,754.26 3,597.66 0.00 0.00 5,927,404.19 1,604,040.17 18.49 4.87 5,772.92 73.77 100.00 3,774.64 3,618.04 0.00 0.00 5,927,391.68 1,604,109.05 18.91 4.99 Start DLS 2.07 TFO 89.22 5,800.00 73.78 100.59 3,782.21 3,625.61 2.07 89.22 5,927,386.90 1,604,13461 19.04 5.03 5,900.00 73.82 102.74 3,810.11 3,653.51 2.07 89.05 5,927,366.99 1,604,228.53 19.49 5.20 6,000.00 73.89 104.90 3,837.91 3,681.31 2.07 88.45 5,927,343.56 1,604,32167 19.92 5.36 6,100.00 73.98 107.06 3,865.59 3,708.99 2.07 87.85 5,927,316.62 1,604,413.90 20.31 5.53 6,120.44 74.00 107.50 3,871.23 3,714.63 2.07 87.25 5,927,310.69 1,604,432.63 20.39 5.56 Start 4137.22 hold at 6120.44 MD 6,200.00 74.00 107.50 3,893.16 3,736.56 0.00 0.00 5,927,287.31 1,604,505.44 20.82 5.69 6,300.00 74.00 107.50 3,920.72 3,764.12 0.00 0.00 5,927,257.93 1,604,596.95 21.41 5.86 6,400.00 74.00 107.50 3,948.28 3,791.68 0.00 0.00 5,927,228.55 1,604,688.47 21.99 6.02 6,500.00 74.00 107.50 3,975.85 3,819.25 0.00 0.00 5,927,199.17 1,604,779.98 22.57 6.19 6,600.00 74.00 107.50 4,003.41 3,846.81 0.00 0.00 5,927,169.79 1,604,871.50 23.16 6.36 6,700.00 74.00 107.50 4,030.98 3,874.38 0.00 0.00 5,927,140.40 1,604,963.02 23.74 6.52 6,800.00 74.00 107.50 4,058.54 3,901.94 0.00 0.00 5,927,111.02 1,605,054.53 24.33 6.69 6,900.00 74.00 107.50 4,086.10 3,929.50 0.00 0.00 5,927,081.64 1,605,146.05 24.91 6.86 11/5/2014 2:17:16PM Page 6 COMPASS 5000.1 Build 65 ORIGINAL 0 • Schlumberger Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316` Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS Oleg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) p1100usft) (") (usft) (usft) (usft) (usft) 7,000.00 74.00 107.50 4,113.67 3,957.07 0.00 0.00 5,927,05226 1,605,237.56 25.50 7.03 7,100.00 74.00 107.50 4,141.23 3,984.63 0.00 0.00 5,927,022.88 1,605,329.08 26.08 7.19 7,200.00 74.00 107.50 4,168.79 4,012.19 0.00 0.00 5,926,993.50 1,605,420.59 26.67 7.36 7,300.00 74.00 107.50 4,196.36 4,039.76 0.00 0.00 5,926,964.11 1,605,512.11 27.25 7.53 7,380.69 74.00 107.50 4,218.60 4,062.00 0.00 0.00 5,926,940.41 1,605,585.96 27.84 7.70 C-40 7,400.00 74.00 107.50 4,223.92 4,067.32 0.00 0.00 5,926,934.73 1,605,603.63 27.84 7.70 7,500.00 74.00 107.50 4,251.49 4,094.89 0.00 0.00 5,926,905.35 1,605,695.14 28.42 7.86 7,600.00 74.00 107.50 4,279.05 4,122.45 0.00 0.00 5,926,875.97 1,605,786.66 29.01 8.03 7,700.00 74.00 107.50 4,306.61 4,150.01 0.00 0.00 5,926,846.59 1,605,878.17 29.60 8.20 7,800.00 74.00 107.50 4,334.18 4,177.58 0.00 0.00 5,926,817.21 1,605,969.69 30.18 8.37 7,900.00 74.00 107.50 4,361.74 4,205.14 0.00 0.00 5,926,787.82 1,606,061.21 30.77 8.54 8,000.00 74.00 107.50 4,389.30 4,232.70 0.00 0.00 5,926,758.44 1,606,152.72 31.36 8.70 6,037.35 74.00 107.50 4,399.60 4,243.00 0.00 0.00 5,926,747.47 1,606,186.90 31.95 8.87 C-37 8,100.00 74.00 107.50 4,416.87 4,260.27 0.00 0.00 5,926,729.06 1,606,244.24 31.95 8.87 8,200.00 74.00 107.50 4,444.43 4,287.83 0.00 0.00 5,926,699.68 1,606,335.75 32.53 9.04 8,300.00 74.00 107.50 4,472.00 4,315.40 0.00 0.00 5,926,670.30 1,606,427.27 33.12 9.21 8,400.00 74.00 107.50 4,499.56 4,342.96 0.00 0.00 5,926,640.92 1,606,518.78 33.71 9.38 8,500.00 74.00 107.50 4,527.12 4,370.52 0.00 0.00 5,926,611.53 1,606,610.30 34.30 9.54 8,600.00 74.00 107.50 4,554.69 4,398.09 0.00 0.00 5,926,582.15 1,606,701.82 34.88 9.71 8,700.00 74.00 107.50 4,582.25 4,425.65 0.00 0.00 5,926,552.77 1,606,793.33 35.47 9.88 8,800.00 74.00 107.50 4,609.81 4,453.21 0.00 0.00 5,926,523.39 1,606,884.85 36.06 10.05 8,900.00 74.00 107.50 4,637.38 4,480.78 0.00 0.00 5,926,494.01 1,606,976.36 36.65 10.22 9,000.00 74.00 107.50 4,664.94 4,508.34 0.00 0.00 5,926,464.63 1,607,067.88 37.24 10.39 9,100.00 74.00 107.50 4,692.51 4,535.91 0.00 0.00 5,926,435.24 1,607,159.40 37.83 10.55 9,200.00 74.00 107.50 4,720.07 4,563.47 0.00 0.00 5,926,405.86 1,607,250.91 38.41 10.72 11/52014 2:17:16PM Papel COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316* Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-3t6 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 9,300.00 74.00 107.50 4,747.63 4,591.03 0.00 0.00 5,926,376.48 1,607,342.43 39.00 10.89 9,400.00 74.00 107.50 4,775.20 4,618.60 0.00 0.00 5,926,347.10 1,607,433.94 39.59 11.06 9,500.00 74.00 107.50 4,802.76 4,646.16 0.00 0.00 5,926,317.72 1,607,525.46 40.18 11.23 9,600.00 74.00 107.50 4,830.32 4,673.72 0.00 0.00 5,926,288.34 1,607,616.97 40.77 11.40 9,700.00 74.00 107.50 4,857.89 4,701.29 0.00 0.00 5,926,258.96 1,607,708.49 41.36 11.57 9,800.00 74.00 107.50 4,885.45 4,728.85 0.00 0.00 5,926,229.57 1,607,800.01 41.95 11.73 9,900.00 74.00 107.50 4,913.02 4,756.42 0.00 0.00 5,926,200.19 1,607,891.52 42.54 11.90 10,000.00 74.00 107.50 4,940.58 4,783.98 0.00 0.00 5,926,170.81 1,607,983.04 43.13 12.07 10,100.00 74.00 107.50 4,968.14 4,811.54 0.00 0.00 5,926,141.43 1,608,074.55 43.71 12.24 10,119.80 74.00 107.50 4,973.60 4,817.00 0.00 0.00 5,926,135.61 1,608,092.67 44.30 12.41 T7 10,200.00 74.00 107.50 4,995.71 4,839.11 0.00 0.00 5,926,112.05 1,608,166.07 44.30 12.41 10,257.66 74.00 107.50 5,011.60 4,855.00 0.00 0.00 5,926,095.11 1,608,218.84 44.64 12.51 • Start DLS 4.30 TFO-0.51 10,300.00 75.82 107.48 5,022.62 4,866.02 4.30 -0.51 5,926,082.62 1,608,257.76 44.89 12.58 10,386.92 79.56 107.45 5,041.15 4,884.55 4.30 -0.50 5,926,056.71 1,608,338.61 45.40 12.73 Start Turn 0.00 10,400.00 79.56 107.45 5,043.52 4,886.92 0.00 0.00 5,926,052.79 1,608,350.86 45.47 12.75 10,500.00 79.56 107.45 5,061.64 4,905.04 0.00 0.00 5,926,022.81 1,608,444.51 46.05 12.92 10,600.00 79.56 107.45 5,079.76 4,923.16 0.00 0.00 5,925,992.83 1,608,538.16 46.62 13.10 10,700.00 79.56 107.45 5,097.88 4,941.28 0.00 0.00 5,925,962.86 1,608,631.82 47.19 13.27 10,800.00 79.56 107.45 5,116.00 4,959.40 0.00 0.00 5,925,932.88 1,608,725.47 47.76 13.44 10,900.00 79.56 107.45 5,134.12 4,977.52 0.00 0.00 5,925,902.90 1,608,819.13 48.34 13.62 11,000.00 79.56 107.45 5,152.24 4,995.64 0.00 0.00 5,925,872.92 1,608,912.78 48.91 13.79 11,100.00 79.56 107.45 5,170.36 5,013.76 0.00 0.00 5,925,842.94 1,609,006.43 49.49 13.96 11,162.01 79.56 107.45 5,181.60 5,025.00 0.00 0.00 5,925,824.35 1,609,064.51 50.06 14.14 T-4.1 11,200.00 79.56 107.45 5,188.48 5,031.88 0.00 0.00 5,925,812.97 1,609,100.09 50.06 14.14 11/5/2014 2:17:16PM Page 8 COMPASS 5000.1 Build 65 JRG1NAL • • Schlumberger -...- Plan Summary COIIOCOPhillip5 Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316` Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 IPlanned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (1 (usft) (usft) (°1100usft) (°) (usft) (usft) (usft} (usft) 11,300.00 79.56 107.45 5,206.60 5,050.00 0.00 0.00 5,925,782.99 1,609,193.74 50.64 14.31 11,400.00 79.56 107.45 5,224.72 5,068.12 0.00 0.00 5,925,753.01 1,609,287.40 51.21 14.48 11,500.00 79.56 107.45 5,242.85 5,086.25 0.00 0.00 5,925,723.03 1,609,381.05 51.79 14.66 11,600.00 79.56 107.45 5,260.97 5,104.37 0.00 0.00 5,925,693.05 1,609,474.70 52.36 14.83 11,700.00 79.56 107.45 5,279.09 5,122.49 0.00 0.00 5,925,663.08 1,609,568.36 52.94 15.01 11,800.00 79.56 107.45 5,297.21 5,140.61 0.00 0.00 5,925,633.10 1,609,662.01 53.51 15.18 11,838.67 79.56 107.45 5,304.21 5,147.61 0.00 0.00 5,925,621.51 1,609,698.23 53.73 15.25 Start DLS 4.29 TFO 87.62 11,900.00 79.68 110.12 5,315.27 5,158.67 4.29 87.62 5,925,601.78 1,609,755.23 53.86 15.35 12,000.00 79.92 114.48 5,332.98 5,176.38 4.29 87.14 5,925,563.97 1,609,846.06 53.80 15.53 12,067.05 80.12 117.39 5,344.60 5,188.00 4.29 86.37 5,925,534.78 1,609,905.28 53.42 15.70 T-3.1 12,100.00 80.22 118.83 5,350.22 5,193.62 4.29 85.86 5,925,519.34 1,609,933.83 53.42 15.70 12,137.16 80.35 120.44 5,356.49 5,199.89 4.29 85.62 5,925,501.06 1,609,965.57 53.19 15.76 Start 20.00 hold at 12137.16 MD-7-518"x 9-718" 12,157.16 80.35 120.44 5,359.85 5,203.25 0.00 0.00 5,925,490.99 1,609,982.51 53.31 15.76 Start DLS 4.51 TFO 85.38 12,200.00 80.51 122.39 5,366.97 5,210.37 4.51 85.38 5,925,468.78 1,610,018.44 53.02 15.76 12,300.00 80.93 126.94 5,383.10 5,226.50 4.51 85.05 5,925,412.24 1,610,099.28 52.16 15.77 12,400.00 81.40 131.48 5,398.47 5,241.87 4.51 84.32 5,925,349.39 1,610,175.48 51.02 15.78 12,448.41 81.65 133.68 5,405.60 5,249.00 4.51 83.62 5,925,316.81 1,610,210.56 49.62 15.81 Top Bermuda 12,500.00 81.93 136.01 5,412.97 5,256.37 4.51 83.30 5,925,280.62 1,610,246.57 49.62 15.81 12,600.00 82.51 140.53 5,426.51 5,269.91 4.51 82.96 5,925,206.36 1,610,312.11 47.97 15.84 12,700.00 83.13 145.03 5,439.02 5,282.42 4.51 82.35 5,925,127.07 1,610,371.68 46.09 15.88 12,721.80 83.27 146.01 5,441.60 5,285.00 4.51 81.79 5,925,109.16 1,610,383.84 44.00 15.93 Top Berm Seis 12,800.00 83.79 149.52 5,450.41 5,293.81 4.51 81.67 5,925,043.24 1,610,424.93 44.00 15.93 11/5/2014 2.17:15PM Page 9 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316' Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.En-or (usft) (°) (°) (usft) (usft) (°NOOusft) (°) (usft) (usft) (usft) (usft) 12,900.00 84.50 154.00 5,460.61 5,304.01 4.51 81.28 5,924,955.38 1,610,471.52 41.72 15.99 12,958.71 84.93 156.63 5,466.03 5,309.43 4.51 80.82 5,924,902.15 1,610,495.65 40.30 16.03 Start 29.08 hold at 12958.71 MD 12,987.79 84.93 156.63 5,468.60 5,312.00 0.00 0.00 5,924,875.50 1,610,507.00 40.57 16.05 Start DLS 3.00 TFO 50.40 13,000.00 85.16 156.91 5,469.66 5,313.06 3.00 50.40 5,924,864.30 1,610,511.74 40.48 16.06 13,100.00 87.08 159.22 5,476.43 5,319.83 3.00 50.37 5,924,771.57 1,610,548.51 39.69 16.13 13,135.74 87.76 160.05 5,478.04 5,321.44 3.00 50.21 5,924,738.04 1,610,560.76 39.42 16.16 Start 77.40 hold at 13135.74 MD 13,200.00 87.76 160.05 5,480.55 5,323.95 0.00 0.00 5,924,677.58 1,610,582.35 33.67 15.87 13,213.14 87.76 160.05 5,481.06 5,324.46 0.00 0.00 5,924,665.21 1,610,586.77 33.71 15.87 Start DLS 3.00 TFO-83.40 13,281.83 88.00 158.00 5,483.60 5,327.00 3.00 -83.40 5,924,601.00 1,610,611.00 35.45 15.89 Start DLS 2.00 TFO-26.65 13,300.00 88.32 157.84 5,484.18 5,327.58 2.00 -26.65 5,924,584.14 1,610,617.74 35.62 15.89 13,318.32 88.65 157,67 5,484.67 5,328.07 2.00 -26.65 5,924,567.15 1,610,624.58 35.78 15.89 Start 1171.36 hold at 13318.32 MD 13,400.00 88.65 157.67 5,486.59 5,329.99 0.00 0.00 5,924,491.46 1,610,655.20 35.98 15.91 13,500.00 88.65 157.67 5,488.94 5,332.34 0.00 0.00 5,924,398.80 1,610,692.70 36.24 15.94 13,600.00 88.65 157.67 5,491.29 5,334.69 0.00 0.00 5,924,306.13 1,610,730.19 36.50 15.97 13,700.00 88.65 157.67 5,493.64 5,337.04 0.00 0.00 5,924,213.47 1,610,767.68 36.77 16.00 13,800.00 88.65 157.67 5,496.00 5,339.40 0.00 0.00 5,924,120.80 1,610,805.17 37.05 16.03 13,900.00 88.65 157.67 5,498.35 5,341.75 0.00 0.00 5,924,028.14 1,610,842.66 37.33 16.06 14,000.00 88.65 157.67 5,500.70 5,344.10 0.00 0.00 5,923,935.47 1,610,880.16 37.62 16.10 14,100.00 88.65 157.67 5,503.05 5,346.45 0.00 0.00 5,923,842.81 1,610,917.65 37.92 16.14 14,200.00 88.65 157.67 5,505.40 5,348.80 0.00 0.00 5,923,750.14 1,610,955.14 38.22 16.18 14,300.00 88.65 157.67 5,507.76 5,351.16 0.00 0.00 5,923,657.48 1,610,992.63 38.53 16.22 14,400.00 88.65 157.67 5,510.11 5,353.51 0.00 0.00 5,923,564.81 1,611,030.12 38.85 16.26 11/5/2014 2:17:16PM Page 10 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316` Project: Kuparuk River Unit ND Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS OLeg TFace Northing Easting Lat.Error Vert.Error (usft) (1 (°) (usft) (usft) ('/100usft) (') (usft) (usft) (usft) (usft) 14,489.68 88.65 157.67 5,512.22 5,355.62 0.00 0.00 5,923,481 71 1,611,063.75 39.13 16.30 Start DLS 2.00 TFO 55.05 14,500.00 88.77 157.84 5,512.45 5,355.85 2.00 55.05 5,923,472.14 1,611,067.60 39.04 16.31 14,600.00 89.92 159.48 5,513.59 5,356.99 2.00 55.05 5,923,378.83 1,611,103.49 38.13 16.35 14,607.27 90.00 159.60 5,513.60 5,357.00 2.00 55.03 5,923,372.00 1,611,106.00 38.07 16.36 Start DLS 2.00 TFO 3.39 14,655.34 90.96 159.66 5,513.20 5,356.60 2.00 3.39 5,923,326.85 1,611,122.50 38.19 16.38 Start 334.17 hold at 14655.34 MD 14,700.00 90.96 159.66 5,512.45 5,355.85 0.00 0.00 5,923,284.91 1,611,137.80 38.34 16.40 14,800.00 90.96 159.66 5,510.77 5,354.17 0.00 0.00 5,923,190.99 1,611,172.06 38.68 16.45 14,900.00 90.96 159.66 5,509.10 5,352.50 0.00 0.00 5,923,097.07 1,611,206.33 39.03 16.51 14,989.51 90.96 159.66 5,507.60 5,351.00 0.00 0.00 5,923,013.00 1,611,237.00 39.34 16.55 TD at 14989.51-3.112"x 6" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (') (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2L-316 T2 23Sep14 EB 0.00 0.00 5,483.60 -2,755.85 9,675.57 5,924,601.00 1,610,611.00 70°12'19.597 N 150'14'25.068 W -plan hits target center -Circle(radius 100.00) 2L-316 Heel 23Sep14 El 0.00 0.00 5,468.60 -2,481.87 9,570.12 5,924,875.50 1,610,507.00 70°12'22.293 N 150°14'28.118 W -plan hits target center -Circle(radius 100.00) 2L-316 T3 23Sep14 EB 0.00 0.00 5,513.60 -3,982.36 10,177.03 5,923,372.00 1,611,106.00 70°12'7.527 N 150'14'10.563 W -plan hits target center -Circle(radius 100.00) 2L-316 Toe 23Sep14 EB 0.00 0.00 5,507.60 -4,340.71 10,309.92 5,923,013.00 1,611,237.00 70°12'4.001 N 150°14'6.722 W -plan hits target center -Circle(radius 100.00) 11/5/2014 2:17:16PM Page 11 COMPASS 5000.1 Build 65 ORIGiNAL • • Schlumberger v-- Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316` Project: Kuparuk River Unit TVD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name f') I 2,509.63 2,401.50 10-3/4"x13-1/2" 10-3/4 13-1/2 14,989.51 5,507.60 3-1/2"x6" 3-1/2 6 12,137.16 5,356.49 7-5/8"x 9-7/8" 7-5/8 9-7/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 r) 12,448.41 5,405.60 Top Bermuda 0.00 12,067.05 5,344.60 T-3.1 0.00 1,407.67 1,389.60 Pfrost 0.00 8,037.35 4,399.60 C-37 0.00 12,721.80 5,441.60 Top Berm Seis 0.00 2,687.61 2,545.60 CAMP-SST 0.00 10,119.80 4,973.60 T-7 0.00 2,618.39 2,490.60 C-80 0.00 5,683.33 3,749.60 C-50 0.00 7,380.69 4,218.60 C-40 0.00 11,162.01 5,181.60 T-4.1 0.00 11152014 2:17:16PM Page 12 COMPASS 5000.1 Build 65 ORIGINAL • • Schlumberger Plan Summary ConocoPhillips Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-316-Slot 2L-316* Project: Kuparuk River Unit ND Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: plan:39.5+117.1 @ 156.60usft(Doyon 25) Well: Plan:2L-316 North Reference: True Wellbore: Plan:2L-316 Survey Calculation Method: Minimum Curvature Design: 2L-316wp06.1 Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 311.50 311.50 0.00 0.00 Start Build 1.50 561.50 561.32 8.15 -0.71 Start DLS 1.50 TFO 10.00 861.50 859.61 39.38 -1.39 Start DLS 2.00 TFO 10.00 1,411.50 1,393.22 168.74 8.81 Start 100.00 hold at 1411.50 MD 1,511.50 1,487.68 201.35 12.39 Start DLS 3.51 TFO 107.10 2,509.63 2,401.50 394.42 317.83 Start 20.00 hold at 2509.63 MD 2,529.63 2,418.08 395.40 328.97 Start DLS 3.00 TFO 25.00 3,011.50 2,782.70 397.14 642.06 Start DLS 2.54 TFO 14.45 4,072.92 3,299.50 284.51 1,551.02 Start 1700.00 hold at 4072.92 MD 5,772.92 3,774.64 1.07 3,158.48 Start DLS 2.07 TFO 89.22 6,120.44 3,871.23 -78.23 3,482.50 Start 4137.22 hold at 6120.44 MD 10,257.66 5,011.60 -1,274.12 7,275.39 Start DLS 4.30 TFO-0.51 10,386.92 5,041.15 -1,311.89 7,395.37 Start Turn 0.00 11,838.67 5,304.21 -1,740.03 8,757.38 Start DLS 4.29 TFO 87.62 12,137.16 5,356.49 -1,859.08 9,025.37 Start 20.00 hold at 12137.16 MD 12,157.16 5,359.85 -1,869.07 9,042.37 Start DLS 4.51 TFO 85.38 12,958.71 5,466.03 -2,455.28 9,558.63 Start 29.08 hold at 12958.71 MD 12,987.79 5,468.60 -2,481.87 9,570.12 Start DLS 3.00 TFO 50.40 13,135.74 5,478.04 -2,619.05 9,624.60 Start 77.40 hold at 13135.74 MD 13,213.14 5,481.06 -2,691.75 9,651.00 Start DLS 3.00 TFO-83.40 13,281.83 5,483.60 -2,755.85 9,675.57 Start DLS 2.00 TFO-26.65 13,318.32 5,484.67 -2,789.62 9,689.33 Start 1171.36 hold at 13318.32 MD 14,489.68 5,512.22 -3,872.87 10,134.20 Start DLS 2.00 TFO 55.05 14,607.27 5,513.60 -3,982.36 10,177.03 Start DLS 2.00 TFO 3.39 14,655.34 5,513.20 -4,027.43 10,193.77 Start 334.17 hold at 14655.34 MD 14,989.51 5,507.60 -4,340.71 10,309.92 TD at 14989.51 Checked By: Approved By: Date: 11/5/2014 2.17:16PM Page 13 COMPASS 5000.1 Build 65 ORIGINAL S ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-316 Plan: 2L-316 2L-316wp06.1 4,1 111 4 Clearance Summary Anticollision Report 05 November,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Well Coordinates: 5,927,407.11 N,1,600,950.92 E(70°12'46.76"N,150°19'05.86"W) Datum Height: plan:39.5+117.1 i 156.60usft(Doyon 25) Scan Range: 0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied _' t? Version: 5000.1 Build: 65 3 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference r( Scan Type: 25.00 ,ii pu[ ORIGINAL • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316 -2L-316wpO6.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range:0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 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 Kuparuk 2L Pad 2L-03-2L-03-2L-03 112.00 195.04 112.00 193.04 100.00 97.599 Centre Distance Pass-Major Risk 2L-03-2L-03-2L-03 312.00 195.96 312.00 190.65 300.00 36.936 Clearance Factor Pass-Major Risk 2L-301-2L-301-2L-301 313.54 223.63 313.54 217.44 300.00 36.101 Centre Distance Pass-Major Risk 2L-301-2L-301-2L-301 513.01 224.80 513.01 214.65 500.00 22.137 Clearance Factor Pass-Major Risk 2L-304-2L-304-2L-304 41.70 180.19 41.70 179.15 27.28 173.755 Centre Distance Pass-Major Risk 2L-304-2L-304-2L-304 264.42 180.78 264.42 176.21 250.00 39.618 Clearance Factor Pass-Major Risk 2L-305-2L-305-2L-305 156.60 165.01 156.60 162.63 146.10 69.449 Centre Distance Pass-Major Risk 2L-305-2L-305-2L-305 612.36 166.83 612.36 157.03 600.00 17.036 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 251.45 149.24 251.45 144.78 250.00 33.469 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 276.45 149.31 276.45 144.44 275.00 30.659 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 251.45 149.24 251.45 144.78 250.00 33.469 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 276.45 149.31 276.45 144.44 275.00 30.659 Clearance Factor Pass-Major Risk 2L-307-2L-307-2L-307 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307-2L-307 6,684.89 373.86 6,684.89 127.02 5,800.00 1.515 Clearance Factor Pass-Major Risk 2L-307-2L-307L1-2L-307L1 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L1-2L-307L1 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-2L-307L2 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L2-2L-307L2 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-309-2L-309-2L-309 41.30 104.98 41.30 104.00 33.98 106.538 Centre Distance Pass-Major Risk 2L-309-2L-309-2L-309 332.34 107.69 332.34 101.35 325.00 16.980 Clearance Factor Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 41.30 104.98 41.30 103.95 33.98 101.700 Centre Distance Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 332.34 107.69 332.34 101.30 325.00 16.856 Clearance Factor Pass-Major Risk 2L-310-2L-310-2L-310 214.70 89.56 214.70 85.78 200.00 23.716 Centre Distance Pass-Major Risk 2L-310-2L-310-2L-310 9,421.38 257.58 9,421.38 44.29 8,575.00 1.208 Clearance Factor Pass-Major Risk 2L-311-2L-311-2L-311 213.30 74.89 213.30 71.40 200.00 21.475 Centre Distance Pass-Major Risk • 2L-311-2L-311-2L-311 ® - - - - 05 November,2014-14:18 Page 2 of 7 COMPASS -.. _ ORIGINAL 11111 • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wp06.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range: 0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 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 2L-312(Cassidy)-2L-312-2L-312 401.89 60.41 401.89 52.80 400.00 7.943 Centre Distance Pass-Major Risk 2L-312(Cassidy)-2L-312-2L-312 451.97 60.84 451.97 52.25 450.00 7.086 Clearance Factor Pass-Major Risk 2L-313-2L-313-2L-313 285.55 45.12 285.55 40.72 275.00 10.254 Centre Distance Pass-Major Risk 2L-313-2L-313-2L-313 610.52 45.76 610.52 36.00 600.00 4.691 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 338.31 28.28 338.31 22.37 325.00 4.781 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 488.45 29.49 488.45 21.21 475.00 3.560 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 338.31 28.28 338.31 22.37 325.00 4.781 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 488.45 29.49 488.45 21.21 475.00 3.560 Clearance Factor Pass-Major Risk 2L-315-2L-315-2L-315 460.50 11.04 460.50 3.69 450.00 1.501 Centre Distance Pass-Major Risk 2L-315-2L-315-2L-315 510.42 11.47 510.42 3.29 500.00 1.402 Clearance Factor Pass-Major Risk 2L-317-2L-317-2L-317 403.30 11.16 403.30 4.49 400.00 1.674 Clearance Factor Pass-Major Risk 2L-317-2L-317A-2L-317A 403.30 11.16 403.30 4.49 400.00 1.674 Clearance Factor Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 437.75 29.45 437.75 22.08 425.00 3.993 Centre Distance Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 487.40 29.81 487.40 21.62 475.00 3.638 Clearance Factor Pass-Major Risk 2L-319-2L-319-2L-319 882.03 20.39 882.03 3.92 875.00 1.238 Clearance Factor Pass-Major Risk 2L-320-2L-320-2L-320 549.32 52.71 549.32 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320-2L-320 598.67 52.94 598.67 41.24 600.00 4.525 Clearance Factor Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 549.32 52.71 549.32 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 598.67 52.94 598.67 41.24 600.00 4.525 Clearance Factor Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 549.32 52.71 549.32 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 598.67 52.94 598.67 41.24 600.00 4.525 Clearance Factor Pass-Major Risk 2L-321-2L-321-2L-321 410.14 73.82 410.14 67.33 400.00 11.378 Centre Distance Pass-Major Risk 2L-321-2L-321-2L-321 559.21 75.10 559.21 66.15 550.00 8.384 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322-2L-322 326.71 89.20 326.71 82.86 325.00 14.078 Centre Distance Pass-Major Risk 2L-322(North)-2L-322-2L-322 450.84 90.27 450.84 81.49 450.00 10.282 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 337.73 89.20 337.73 82.65 325.00 13.614 Centre Distance Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 461.79 90.49 461.79 81.49 450.00 10.058 Clearance Factor Pass-Major Risk 2L-323-2L-323-2L-323 385.21 104.40 385.21 98.15 375.00 16.718 Centre Distance Pass-Major Risk 2L-323-2L-323-21-323 583.94 105.77 583.94 96.24 575.00 11.106 Clearance Factor Pass-Major Risk 2L-325-2L-325-2L-325 156.60 134.89 156.60 132.39 146.20 53.826 Centre Distance Pass-Major Risk 05 November,2014- 14:18 Page 3 of 7 COMPASS ORIGINAL • • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wpO6.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range:0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (tisk) usft 2L-325-2L-325-2L-325 235.39 135.61 235.39 131.89 225.00 36.474 Clearance Factor Pass-Major Risk 2L-326-2L-326-2L-326 41.20 149.94 41.20 148.91 34.30 145.418 Centre Distance Pass-Major Risk 2L-326-2L-326-2L-326 431.07 152.62 431.07 144.23 425.00 18.173 Clearance Factor Pass-Major Risk 2L-327-2L-327-2L-327 458.50 163.54 458.50 154.62 450.00 18.342 Centre Distance Pass-Major Risk 2L-327-2L-327-2L-327 630.91 164.94 630.91 152.62 625.00 13.388 Clearance Factor Pass-Major Risk 2L-329-2L-329-2L-329 384.96 193.14 384.96 186.87 375.00 30.813 Centre Distance Pass-Major Risk 2L-329-2L-329-2L-329 434.58 193.59 434.58 186.51 425.00 27.334 Clearance Factor Pass-Major Risk 2L-329-2L-329A-2L-329A 384.96 193.14 384.96 186.87 375.00 30.813 Centre Distance Pass-Major Risk 2L-329-2L-329A-2L-329A 434.58 193.59 434.58 186.51 425.00 27.334 Clearance Factor Pass-Major Risk 2L-330-2L-330-2L-330 532.07 207.33 532.07 197.76 525.00 21.680 Centre Distance Pass-Major Risk 2L-330-2L-330-2L-330 580.43 207.68 580.43 197.40 575.00 20.200 Clearance Factor Pass-Major Risk 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 532.71 207.33 532.71 197.80 525.00 21.766 Centre Distance Pass-Major Risk 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 581.05 207.69 581.05 197.45 575.00 20.275 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 300.00 120.07 300.00 114.73 300.00 22.503 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 551.07 121.85 551.07 112.13 550.00 12.533 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 300.00 120.07 300.00 114.73 300.00 22.503 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 551.07 121.85 551.07 112.13 550.00 12.533 Clearance Factor Pass-Major Risk Plan:2L-328(Sierra)-2L-328-2L-328wp05 288.20 179.83 288.20 174.72 275.00 35.248 Centre Distance Pass-Major Risk Plan:2L-328(Sierra)-2L-328-2L-328wp05 585.10 181.23 585.10 171.39 575.00 18.425 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 299.50 210.06 299.50 204.81 300.00 39.992 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 349.80 210.28 349.80 204.20 350.00 34.597 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1(wp01 299.50 210.06 299.50 204.81 300.00 39.992 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1(wp01 349.80 210.28 349.80 204.20 350.00 34.597 Clearance Factor Pass-Major Risk Plan:Kuparuk 2S Pad 05 November.2014- 14:18 Page 4 of 7 COMPASS 0 i i ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wpO6.1 Survey tool program From To Survey/Plan Survey Tool tusk) (usk) 39.50 1,000.00 2L-316wp06.1 GYD-GC-SS 1,000.00 2,500.00 2L-316wp06.1 MWD 1,000.00 2,500.00 2L-316wp06.1 MWD+IFR-AK-CAZ-SC 2,500.00 3,500.00 2L-316wp06.1 MWD 2,500.00 12,137.16 2L-316wp06.1 MWD+IFR-AK-CAZ-SC 12,137.16 13,200.00 2L-316wp06.1 MWD 12,137.16 14,989.51 2L-316wp06.1 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 05 November,2014- 14:18 Page 5 of 7 COMPASS ORIGINAL • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-316 Plan: 2L-316 2L-316wp06.1 Clearance Summary Anticollision Report 05 November,2014 II Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 111 Well Coordinates: 5,927,407.11 N,1,600,950.92 E(70'12'46.76"N,150°19'05.86"W) Datum Height: plan:39.5+117.1 @ 156.60usft(Doyon 25) Scan Range: 0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited !L' Geodetic Scale Factor Applied it'll Version: 5000.1 Build: 65 Scan Type: GLOBAL FILTER APPLIED.All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 I • • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316 -2L-316wp06.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range: 0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 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 Kuparuk 2L Pad 2L-03-2L-03-2L-03 112.00 195.04 112.00 193.04 100.00 97.599 Centre Distance Pass-Major Risk 2L-03-2L-03-2L-03 312.00 195.96 312.00 190.65 300.00 36.936 Clearance Factor Pass-Major Risk 2L-301-2L-301-2L-301 313.54 223.63 313.54 217.44 300.00 36.101 Centre Distance Pass-Major Risk 2L-301-2L-301-2L-301 513.01 224.80 513.01 214.65 500.00 22.137 Clearance Factor Pass-Major Risk 2L-304-2L-304-2L-304 41.70 180.19 41.70 179.15 27.28 173.755 Centre Distance Pass-Major Risk 2L-304-2L-304-2L-304 264.42 180.78 264.42 176.21 250.00 39.618 Clearance Factor Pass-Major Risk 2L-305-2L-305-2L-305 156.60 165.01 156.60 162.63 146.10 69.449 Centre Distance Pass-Major Risk 2L-305-2L-305-2L-305 612.36 166.83 612.36 157.03 600.00 17.036 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 251.45 149.24 251.45 144.78 250.00 33.469 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 276.45 149.31 276.45 144.44 275.00 30.659 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 251.45 149.24 251.45 144.78 250.00 33.469 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 276.45 149.31 276.45 144.44 275.00 30.659 Clearance Factor Pass-Major Risk 2L-307-2L-307-2L-307 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307-2L-307 6,684.89 373.86 6,684.89 127.02 5,800.00 1.515 Clearance Factor Pass-Major Risk 2L-307-2L-307L1-2L-307L1 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L1-2L-307L1 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-2L-307L2 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L2-2L-307L2 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 156.60 135.24 156.60 132.74 152.05 53.965 Centre Distance Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 6,684.89 373.86 6,684.89 105.46 5,800.00 1.393 Clearance Factor Pass-Major Risk 2L-309-2L-309-2L-309 41.30 104.98 41.30 104.00 33.98 106.538 Centre Distance Pass-Major Risk 2L-309-2L-309-2L-309 332.34 107.69 332.34 101.35 325.00 16.980 Clearance Factor Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 41.30 104.98 41.30 103.95 33.98 101.700 Centre Distance Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 332.34 107.69 332.34 101.30 325.00 16.856 Clearance Factor Pass-Major Risk 2L-310-2L-310-2L-310 214.70 89.56 214.70 85.78 200.00 23.716 Centre Distance Pass-Major Risk 2L-310-2L-310-2L-310 9,421.38 257.58 9,421.38 44.29 8,575.00 1.208 Clearance Factor Pass-Major Risk 2L-311-2L-311-2L-311 213.30 74.89 213.30 73.09 200.00 41.822 Centre Distance Pass-Minor 1/200 2L-311-2L-311-2L-311 11,760.89 108.41 11,760.89 46.27 10,850.00 1.745 Clearance Factor Pass-Minor 1/200 05 November 2014- 14:28 Page 2 of 7 COMPASS ORIGINAL 5 , • • Conocol'hillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wpO6.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range:0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 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 2L-312(Cassidy)-2L-312-2L-312 401.89 60.41 401.89 52.80 400.00 7.943 Centre Distance Pass-Major Risk 2L-312(Cassidy)-2L-312-2L-312 451.97 60.84 451.97 52.25 450.00 7.086 Clearance Factor Pass-Major Risk 2L-313-2L-313-2L-313 285.55 45.12 285.55 40.72 275.00 10.254 Centre Distance Pass-Major Risk 2L-313-2L-313-2L-313 610.52 45.76 610.52 36.00 600.00 4.691 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 338.31 28.28 338.31 22.37 325.00 4.781 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 488.45 29.49 488.45 21.21 475.00 3.560 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 338.31 28.28 338.31 22.37 325.00 4.781 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 488.45 29.49 488.45 21.21 475.00 3.560 Clearance Factor Pass-Major Risk 2L-315-2L-315-2L-315 460.50 11.04 460.50 3.69 450.00 1.501 Centre Distance Pass-Major Risk 2L-315-2L-315-2L-315 510.42 11.47 510.42 3.29 500.00 1.402 Clearance Factor Pass-Major Risk 2L-317-2L-317-2L-317 403.30 11.16 403.30 4.49 400.00 1.674 Clearance Factor Pass-Major Risk 2L-317-2L-317A-2L-317A 403.30 11.16 40330 4.49 400.00 1674 Clearance Factor Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 437.75 29.45 437.75 22.08 425.00 3.993 Centre Distance Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 487.40 29.81 487.40 21.62 475.00 3.638 Clearance Factor Pass-Major Risk 2L-319-2L-319-2L-319 882.03 20.39 882.03 3.92 875.00 1.238 Clearance Factor Pass-Major Risk 2L-320-2L-320-2L-320 549.32 52.71 54932 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320-2L-320 598.67 52.94 598.67 41.24 600.00 4.525 Clearance Factor Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 549.32 52.71 549.32 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 598.67 52.94 598.67 41.24 600.00 4525 Clearance Factor Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 549.32 52.71 549.32 41.98 550.00 4.916 Centre Distance Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 598.67 52.94 598.67 41.24 600.00 4.525 Clearance Factor Pass-Major Risk 2L-321-2L-321-2L-321 410.14 73.82 410.14 67.33 400.00 11.378 Centre Distance Pass-Major Risk 2L-321-2L-321-2L-321 559.21 75.10 559.21 66.15 550.00 8.384 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322-2L-322 326.71 89.20 326.71 82.86 325.00 14.078 Centre Distance Pass-Major Risk 2L-322(North)-2L-322-2L-322 450.84 90.27 450.84 81.49 450.00 10.282 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 337.73 89.20 337.73 82.65 325.00 13.614 Centre Distance Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 461.79 90.49 461.79 81.49 450.00 10.058 Clearance Factor Pass-Major Risk 2L-323-2L-323-2L-323 385.21 104.40 38521 98.15 375.00 16.718 Centre Distance Pass-Major Risk 2L-323-2L-323-2L-323 583.94 105.77 583.94 96.24 575.00 11.106 Clearance Factor Pass-Major Risk 2L-325-2L-325-2L-325 156.60 134.89 156.60 132.39 146.20 53.826 Centre Distance Pass-Major Risk 05 November,2014- 14:28 Page 3 of 7 COMPASS ORGNAL • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wp06.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-316-Plan:2L-316-2L-316wp06.1 Scan Range:0.00 to 14,989.51 usft.Measured Depth. Scan Radius is 1,695.00 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 2L-325-2L-325-2L-325 235.39 135.61 235.39 131.89 225.00 36.474 Clearance Factor Pass-Major Risk 2L-326-2L-326-2L-326 41.20 149.94 41.20 148.91 34.30 145.418 Centre Distance Pass-Major Risk 2L-326-2L-326-2L-326 431.07 152.62 431.07 144.23 425.00 18.173 Clearance Factor Pass-Major Risk 2L-327-2L-327-2L-327 458.50 163.54 458.50 154.62 450.00 18.342 Centre Distance Pass-Major Risk 2L-327-2L-327-2L-327 630.91 164.94 630.91 152.62 625.00 13.388 Clearance Factor Pass-Major Risk 2L-329-2L-329-2L-329 384.96 193.14 384.96 186.87 375.00 30.813 Centre Distance Pass-Major Risk 2L-329-2L-329-2L-329 434.58 193.59 434.58 186.51 425.00 27.334 Clearance Factor Pass-Major Risk 2L-329-2L-329A-2L-329A 384.96 193.14 384.96 186.87 375.00 30.813 Centre Distance Pass-Major Risk 2L-329-2L-329A-2L-329A 434.58 193.59 434.58 186.51 425.00 27.334 Clearance Factor Pass-Major Risk 2L-330-2L-330-2L-330 532.07 207.33 532.07 197.76 525.00 21.680 Centre Distance Pass-Major Risk 2L-330-2L-330-2L-330 580.43 207.68 580.43 197.40 575.00 20.200 Clearance Factor Pass-Major Risk 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 532.71 207.33 532.71 197.80 525.00 21.766 Centre Distance Pass-Major Risk 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 581.05 207.69 581.05 197.45 575.00 20.275 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 300.00 120.07 300.00 114.73 300.00 22.503 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 551.07 121.85 551.07 112.13 550.00 12.533 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 300.00 120.07 300.00 114.73 300.00 22.503 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 551.07 121.85 551.07 112.13 550.00 12.533 Clearance Factor Pass-Major Risk Plan:2L-328(Sierra)-2L-328-2L-328wp05 288.20 179.83 288.20 174.72 275.00 35248 Centre Distance Pass-Major Risk Plan:2L-328(Sierra)-2L-328-2L-328wp05 585.10 181.23 585.10 171.39 575.00 18.425 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 299.50 210.06 299.50 204.81 300.00 39.992 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 349.80 210.28 349.80 204.20 350.00 34.597 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1.(wp01 299.50 210.06 299.50 204.81 300.00 39.992 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1(wp01 349.80 210.28 349.80 204.20 350.00 34.597 Clearance Factor Pass-Major Risk Plan:Kuparuk 2S Pad 05 November,2014- 14:28 Page 4 of 7 COMPASS ORtGNAL • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-316-2L-316wp06.1 Survey tool program From To Survey/Plan Survey Tool (u ) (usft) 39.50 1,000.00 2L-316wp06.1 GYD-GC-SS 1,000.00 2,500.00 2L-316wp06.1 MWD 1,000.00 2,500.00 2L-316wp06.1 MWD+IFR-AK-CAZ-SC 2,500.00 3,500.00 2L-316wp06.1 MWD 2,500.00 12,137.16 2L-316wp06.1 MWD+IFR-AK-CAZ-SC 12,137.16 13,200.00 2L-316wp06.1 MWD 12,137.16 14,989.51 2L-316wp06.1 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool lie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 05 November,2014- 14:28 Page 5 of 7 COMPASS ORIGINAL Sec Inc Azi ND +N/-S +E/-W Dleg TFaceSect Target 1 0 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 0.00 21.-316wp06.1 2 . 0 0.00 0.00 311.50 3 561.50 3.75 355.00 561.32 0 00 8.150.71 00 0.00 0.00 50 355.00 -2.66 4 861.50 8.22 0.47 859.61 39.38 -1.39 1.50 10.00 -10.88 39,50 To 14989,51 5 1411.50 19.15 6.27 1393.22 166.74 8.81 2.00 10.00 -32.28 40 300 6 -1511.50 -19.15 6.27 -1487.68 201.35 -- 12.39-- 0.00 0.00 - -36.69 7 2509.63 34.00 85.00 2401.50 394.42 317.83 3.51 107.10 212.97 8 2529.63 34.00 85.00 2418.08 395.40 328.97 0.00 0.00 223.54 300 700 14:22,November 05 2014 9 3011.50 47.45 93.23 2782.70 397.14 642.06 3.00 25.00 526.91 10 4072.92 73.77 100.00 3299.50 284.51 1551.02 2.54 14.45 1436.12 700 1000 11 5772.92 73.77 100.00 3774.64 1.07 3158.48 0.00 0.00 3064.40 SURVEY PROGRAM 12 6120.44 74.00 107.50 3871.23 -78.23 3482.50 2.07 8922 3397.98 leP1n From Depth To s0.vry17bn roof 13 10257.66 74.00 107.50 5011.60 -1274.12 7275.39 0.00 0.00 7367.52 1000 1300 3950 ,000.00 21316,17061(Pb,,:21316)GTO-GCSs 14 10386.92 79.56 107.45 5041.15 -1311.89 7395.37 4.30 -0.51 7493.07 1003.00 2500 OD 2L-316w1706.1(Plan.21:316)MWD 15 11838.67 79.56 107.45 5304.21 -1740.03 8757.38 0.00 0.00 8918.20 1300 1600 1000.00 x500.00 2L-31 a006., 21:316)(171311: Mwo.iPn-accuse 16 12137.16 80.35 120.44 5356.49 -1859.08 9025.37 4.29 87.62 9207.03 2500.00 3500.00 2L (Plow,6,90061(Plow MWD 2500.00 12137.16 2L316w1706.1(171311:21316)MWDdFe-AK.CAZ-SC 17 12157.16 80.35 120.44 5359.85 -1869.07 9042.37 0.00 0.00 9225.94 1600 -"--"---" 1900 12137.16 13200.00 2131.006.1(Rem 2La16)MWD 18 12958.71 84.93 156.63 5466.03 -2455.28 9558.63 4.51 85.38 9868.68 ,207.16 1496951 21:3,6vr906.1(P13n:24318)MWDaIFeA1(-C0.7-5C 19 12987 79 84.93 156.63 5468.60 -2481.87 9570.12 0.00 0.00 9886.27 2L-316 Heel 23Sep14 EB 20 13135.74 87.76 160.05 5478.04 -2619.05 9624.60 3.00 50.40 9972.32 1900 2200 CASING DETAILS 21 13213.14 87.76 160.05 5481.06 -2691.75 9651.00 0.00 0.00 10015.51 22 13281.83 88.00 158.00 5483.60 -2755.85 9675.57 3.00 -83.40 10054.86 2L-316 T2 23Sep14 EB 2200 2500 TVD MD Name Size 23 13318.32 88.65 157.67 5484.67 -2789.62 9689.33 2.00 -26.65 10076.38 2401.50 2509.63 103/4"x 13-1/2" 10-3/4 24 14489.68 88.65 157.67 5512.22 -3872.87 10134.20 0.00 0.00 10770 11 2500 3700 5356.49 12137.16 7-5/8"x 9-7/8" 7-5/8 25 14607.27 90.00 159.60 5513.60 -3982.36 10177.03 2.00 55.05 10838.15 2L-316 T3 23Sep14 EB 5507.60 14989.51 3-1/2"x 6" 3-1/2 26 14655.34 90.96 159.66 5513.20 -4027.43 10193.77 2.00 3.39 10865.29 27 14989.51 90.96 159.66 5507.60 -4340.71 10309.92 0.00 0.00 11053.79 2L316 Toe 23Sep14 EB 3700 ___.......__ 4900 4900 6100 6100 7200 0/360 7200 8400 _'_* j a �em��.;;;_-;------• • 8400 9600 ®�1 a Z" 1 9600 10800 30/330 // / $�1�ra�� „bt, 30 10800 - 12000 e.1. t -Mit`os�� ,N,` 12000 13000 • +a..� 'Ae! �ti .._q .. ,r�t13000 . 14000 �,� , 1,/ \►� P• ' 14000 15000 �,/.i ' 60 V.,,Z g�,:gri t. @0; �� \• J2L-31417611 _ je •.� \,�j � ylAr►ll* i�• ,A�i \;+ti I2L-314 60/300 �� '� �,�@�v\tk i:W4v V it�sx�� ��l ( I 60 .� ��3�.�'@ .ems �� ,6�a ��„ litI/ i /77/0„%, ����. .►� �� ole ,m ' / J ` �i':�h��`�,�/��.',��1 ''�\.AIS, ' , r_ 1 10 7 7 •� `� �� ��` e� �P4tt f`q.041N'.1A. r!pd A. � ��� �/ //17// �j�.� � �� � q�•� ii9�t a 111,.C> o . e. 1,N 1I111�l�I MU ki ,;11 // /``�� �� 1 � i, o i� itat=fir . 1epaJ I:k1511/1.�� I2L-3121 1IINil• / I � � //JJjj��� �j�" r�aa' •.., of�D L►7 011jai.19 1 a: rnSI -d ��� erg C � } las !� r� � ��� IIS Ii:.. ! )1,►,,.„,. ,A� ii.„,I 1;4r .°rf«�r�a%1►1 :4w '� -90/270 1 1' �F ' �IN%:",, .,•-v.l�b�•`►«` <r 44 ,,,to,.. imyry -..1,‘ to i► 7.k;fid/ . , 1► . 7.'r' 90 �� ��. 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'Q �2L-3171 121-321r `\����� \raeall �'`s `.''%� -150/210 � Z �1.A11 � � '3 s 9�L�' 150 I2L-317AI .1414 `' 121-3151 12L-320PB21 __-- t I2L-320PB11- / -180/180 I2L-3181 121-3201 -A- 2Lm.Win 2Lmv2 $ .....30.11,21_90P81 -- x a-at Win 24 ÷12.21,al-r9,al-r9,x-0mv2 -9E- x -$ x0102L01t2wm vs,VO -K$ ma,x'mt COW v0 -tr x } 2L -fr Will, -h- x -A- WaCC-0.x10559 9 z $ Win,u..ny)212,x01200 -j(- WOW,W.MOP2 23201782 v0 ♦ 21320.P11oa21010531,x-0008,128002 SC -a- W3o2(s.al.aloe,2,306 v0 -9- x -$ x '� Ca, 20e Mein).Can 2L30e.2130eaeeBVO -e- Win Oeal.W-CCPO1,2Ls6P8,IC Wan(lab x1.314,x3,4 Vo N $ x322 wenn)'xsx x322 vo -x- PWF 208(Benne).Plug 2L-20...,,213002101 W Vu ▪ W., $ x3,4 am..-11417 (NOM),a-WMA,amu W .88- Parc 2LNI(00101,2L-02t Wmewyo5 W $- x $ x ,• txaef v1, PIN.:x302(W01011.x302,x01250001133 -� 2 -} x � 7.2LJa v2 } P02m:xare(a10105.x3ceL,,1,30x1,(no)v0 4 2 01 VO -�E 2 14 3,(v0� 7.x-026V2 -9 2208 WOISs,2,Pm":26,>,za,2ews(weeme)vo 2L 209 2L 200 x3313 v6 -tr 2 n 1.2 x32,vz $ x3,e.poe, SecInc Azi TVD 41/-S 4.E./-W Dleg TFace�VSect Target 1 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2L-31616506.1 2 WO 0.00 0.00 311.50 3 561.50 3.75 355.00 561.32 8.10.0050.0 .00 .1050.71 1.50 355.00 0.00 -2.66 4 861.50 8.22 0.47 859.61 39.38 -1.39 1.50 10.00 -10.88 39.50 To 14989.51 5 1411.50 19.15 6.27 1393.22 168.74 8.81 2.00 10.00 -32.28 40 300 6 1511.50 -19.15 --6.27 1487.68 201.35 12.39 -0.00 -0.00 -- -36.69 7 2509.63 34.00 85.00 2401.50 394.42 317.83 3.51 107.10 212.97 8 2529.63 34.00 85.00 2418.08 395.40 328.97 0.00 0.00 223.54 300 700 14:26,November 05 2014 9 3011.50 47.45 93.23 2782.70 397.14 642.06 3.00 25.00 526.91 10 4072.92 73.77 100.00 3299.50 284.51 1551.02 2.54 14.45 1436.12 700 1000 11 5772.92 73.77 100.00 3774.64 1.07 3158.48 0.00 0.00 3064.40 SURVEY PROGRAM 12 6120.44 74.00 107.50 3871.23 -78.23 3482.50 2.07 89.22 3397.98 )ap111 From Depth To Survey/Plan Tool 13 10257.66 74.00 107.50 5011.60 -1274.12 7275.39 0.00 0.00 7367.52 1000 -- 1300 39.50 1000.00 2L-315x506.1(Pan:0.-115)GYD-GCSS 14 10386.92 79.56 107.45 5041.15 -1311.89 7395.37 4.30 -0.51 7493.07 ,000.00 2600.00 2L-31exp06.1(Pbn:21,15)MWD 15 11838.67 79.56 107.45 5304.21 -1740.03 8757.38 0.00 0.00 8918.20 1300 1600 1000.00 2500 00 2L-116x535.)(Man:2L-316)6160.173-AK-caz-SC 16 12137.16 80.35 120.44 5356.49 -1859.08 9025.37 4.29 87.62 9207.03 2500.00 3500.00 2L31exp06.1(Man:0.-316)MWO 2500.00 12137.16 2W1exp06.1(5an:2,316)MWD.IFR-Ax-cA2-Sc 17 12157.16 80.35 120.44 5359.85 -1869.07 9042.37 0.00 0.00 9225.94 1600 --- - 1900 12137.16 11200.00 2,316..4p06.1(Pan:2,316)MWD 18 12958.71 84.93 156.63 5466.03 -2455.28 9558.63 4.51 85.38 9868.68 12137.18 13969.51 2,31616506.1(Pan:2W18)MWD.IFR-AK-CAZ-SC 19 12987.79 84.93 156.63 5468.60 -2481.87 9570.12 0.00 0.00 9886.27 2L-316 Heel 23Sep14 EB 20 13135.74 87.76 160.05 5478.04 -2619.05 9624.60 3.00 50.40 9972.32 1900 2200 CASING DETAILS 21 13213.14 87.76 160.05 5481.06 -2691.75 9651.00 0.00 0.00 10015.51 22 13281.83 88.00 158.00 5483.60 -2755.85 9675.57 3.00 -83.40 10054.86 2L-316 T2 23Sep14 EB 2200 2500 ND MD Name Size 23 13318.32 88.65 157.67 5484.67 -2789.62 9689.33 2.00 -26.65 10076.38 2401.50 2509.63 10-3/4"x 13-1/2" 10-3/4 24 14489.68 88.65 157.67 5512.22 -3872.87 10134.20 0.00 0.00 10770.11 2500 3700 5356.49 12137.16 7-5/8"x 9-7/8" 7-5/8 25 14607.27 90.00 159.60 5513.60 -3982.36 10177.03 2.00 55.05 10838.15 2L-316 T3 23Sep14 EB 5507.60 14989.51 3-1/2"x 6" 3-1/2 865.29 27 659.51 90.96 159.66 5507.60 -4340.71 10309.92 0.00 0.00 15.34 90.96 159.66 5513.20 -4027.43 10193.77 2.00 3.39 1053.79 2L-316 Toe 23Sep14 E8 3700 -- 4900 4900 6100 6100 7200 0/360 7200 8400 `2 :i-*Au:ak@�_.1r-- - , 8400 9600 \a>I eA'�?a:�.�►Sr.tar 9600 10800 -30/330 iilis<�,.:i i3��4a ►moo 30 10800 - 12000 //‘••0•00. >>, 'm ''����`i" ��:�� r 12000 13000 ikWAN Ir lila iia ����.�,,, �"�. � *��\��. 13000 14000 i` i voriti, 117-110.,,0141,1%,a•�d;,1��`el ,* r 14000 15000 - .. 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'�1 �p�_ i i i"�4/�� ♦ �j -moi, 11',,,,�_ -120/240 IaJ•va� - r-,, S �,•:".V..., .a'1!_.� •��s y, iG'ba rSE.pdg 0.4LVA a ,-•,t 120 .123 �►`+QA�! �Iaa�\1;`4.)-7 ` �� gpm��v'�� "i� �,�'` '6�9 ,Ln��//�/ 1�' ilya,►A,���� �2 d 4•: +*,,,..,\\�W& �..'st.Ar a�� '-F s• Iii 9 ♦0$1'�\►i O I2L-3221 1e•''�i`` ".-.��p�,^4.11.00„�, ` �� ��,...„:!..,,,0t,_40& �il'6�. 1', i i� a�9©1.`Ia-%1r 2L-319 44 it l ek.,^ '�' ,,'�'�kk i,A `�.�l�...i./.�..D •moi ,,t0�� \ ��`® �ie l�lammop-,,, p� \'��i+ 4/S�y�J. �1 u�- I2L-3131 �,�` rlb2.411M I. 24W d ---122-3171 122-321x- ;a�d\,_/ AVE \ /i..�� -150/210 �� � ► i:,:�`e � j,� '"ie �• 150 122-31701 1 _._ •,00"---r'•--10.1107.06,------- 12,•3151 12L-320PB21_, _ -_-__- -_- 1 12L-320PB11- -180/180 12,•3181 12L-3201 -A- 503,2233,213 212 $ x 1F 21 -i- x 329,22 -94- 2L '8' 550,5310 2010 VO� -1 V3 -8- x x-34 22030 VO -8- x02,5 3263.22390 V2 -} 2L X ,t 2020,5 -8- xaam ye $ 5 $ 22312(Cr2M/),2,51x,2,-3z W -K- 5220,22020P05 5320792 Vo '41- 5030,P0alim 5130M,2L 325111,02 V2 $ 2L 30615562213x,55600 $ 553,535 2313 V2 43' x -321,2021 $ Plan 2155(5942).712112L-30,0.3002905 V0 $ ziAos(556),x308%01.21300721 0 } x314 Mama),21614,x310 VO $ 2,322 50917,0-32,532 VO -X- Plan 306(50421.Pan:22308531,223®P41xys V0 -9- z '0' x314(laaxg,x-34%01,x314561 V0 $ 2 322 50591.x3220,x3220 w -9- Pan. 311)5'erry,213x3,213x»%03 W -$ 21 '� x31421315,MIS V2 -e- x 2-53,2,323 V2 -K- 50,41 35(2.4.,,,2135,x502 0501(20 -fr x x -} x 2342232802 P 35(Langley),213521.x35110.011 V0 MO, 01 V0 44- x -K- x x-54 2,325 V0 -t- Nut 2517,Pbn.2517.2S17xp5(R6s4A.0 Vo 5332,53013,x�VS 213 z2 VO G I N A� 7.2L327V2 �. 22316x1041 1 41110I ConocoPhillips 2 L-316wp06. 1 Schlumberger Alaska 8 m a Nr M 5 MQ J J 3 J J 2.. J N N A N N N _ Iiill� A : __ � I .®1■IIi,E ,i�ll 160 = '44�__� ,®,111 ®/� ,// ��r, ®fir I IIIja 1���'Ir `',i, ' _u°I 1 il M „,,,,,I.,, r Ir . 1.12 -.unix•;11 1®;Illl b� � h -mmmelm.4411111111111 ,11 II gi 114400'1 •/°' 11111111111w"--- : 104 i 114111,1 r 112 1 �®�i .iii U °°llol_ I '® 'i®l, it 0 1 I I 1 1 I I 1 1 I I I I I 1 1 I MI 1 I I 1 I I I I I I 0 300 600 900 1200 1500 1800 210C Measured Depth Displayed interval could be less than entire range: 39.50 To 14989.51 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 39.50 To 14989.51 Results Limited By: Centre Distance: 1695.00 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1000.00 2L-316wp06.1 (Plan:2L-316) GYD-GC-SS 1000.00 2500.00 2L-316wp06.1 (Plan:2L-316) MWD 1000.00 2500.00 2L-316wp06.1 (Plan:2L-316) MWD+IFR-AK-CAZ-SC 2500.00 3500.00 2L-316wp06.1 (Plan: 2L-316) MWD 2500.00 12137.16 2L-316wp06.1 (Plan: 2L-316) MWD+IFR-AK-CAZ-SC 12137.16 13200.00 2L-316wp06.1 (Plan:2L-316) MWD 12137.16 14989.51 2L-316wp06.1 (Plan:2L-316) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2401.50 2509.63 10-3/4" x 13-1/2" 10-3/4 5356.49 12137.16 7-5/8" x 9-7/8" 7-5/8 5507.60 14989.51 3-1/2"x 6" 3-1/2 LEGEND - 2L-03,2L-03,2L-03 V2 -e- 2L-313,2L-313,2L-313 V2 -e- 2L-325,2L-325,2L-325 V2 - 2L-301,2L-301,2L301 VO --I- 2L-314(Tarawa),2L-314,2L-314 VO -X- 2L-326,2L-326,2L-326 VO - 2L-304,2L-304,2L304 VO -9- 2L-314(Tarawa),2L-314PB1,2L-314PB1 VO -B- 2L-327,2L-327,2L-327 V2 2L-305,2L-305,2L305 V2 -8- 2L-315,2L-315,2L-315 V2 -i- 2L-329,2L-329,2L-329 V2 - 2L-306(Stella),2L-306,2L-306 VO -0- 2L-317,2L-317,2L-317 V2 -A- 2L-329,2L-329A,2L-329A V2 -e- 2L-306(Stella),2L306PB1,2L-306PB1 VO - 2L-317,2L-317A,2L-317A V6 -A- 2L-330,2L-330,2L-330 V8 - 2L-307,2L-307,2L307 V2 -A- 2L-318(Libra),2L-318,2L-318 VO -i- 2L-330,Prelim:2L-330ST1,2L-330ST1wp02 V2 -13- 2L-307,2L-307L1,2L307L1 VO -XF 2L-319,2L-319,2L-319 V4 $ Plan:2L-308(Bertha),Plan:2L-308,2L-308 wp05 VO 2L-307,2L-307L2,2L307L2 VO -' - 2L-320,2L-320,2L320 VO - Plan:2L-308(Bertha),Plan:2L-308PB1,2L-308PB1wp05 VO -e- 2L-307,2L-307L2-01,2L-307L2-01 VO -A- 2L-320,2L-320PB1,2L-320PB1 VO -I-- Plan:2L-328(Siena),2L-328,2L-328wp05 VO - 2L-309,2L-309,2L309 V5 -X- 2L-320,2L-320PB2,2L-320PB2 VO -X-- Prelim:2L-302(Langley),2L-302,2L-302(wp01)VO -B- 2L-309,2L-309PB1,2L-309PB1 V6 -E}- 2L-321,2L-321,2L321 V2 -e- Prelim:2L-302(Langley),2L-302L1,2L-302L1(wp01)VO - 2L-310,2L-310,2L310 VO -e- 2L-322(North),2L-322,2L-322 VO -AT- Plan:2S-17,Plan:2S-17,2S-17wp05(Hybodus)VO -A- 2L-311,2L-311,2L-311 VO -e- 2L-322(North),2L-322A,2L-322A V0 -9-- 2L-316wp06.1 - 2L-312(Cassidy).2L-312,2L-312 VO 61-- 2L-321 2L-323,2L-323 V2 • •ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2L-316 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole / 4-1/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 2L-316 APD Page 11 of 14 Printed: 13-Jan-15 ORIGINAL • •ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 2L-316 well plan. Anti-collision analysis indicates the following separation factors between the planned 2L-316 well plan and the following existing wellbores. 2L-307 (Separation Factor= 1.339, 374' center to center at a depth of 6,685' MD) 2L-310 (Separation Factor= 1.208, 257' center to center at a depth of 9,421' MD) 2L-315 (Separation Factor= 1.402, 11.5' center to center ata depth of 510' MD) 2L-319 (Separation Factor= 1.238, 20.4' center to center at depth of 20.4' MD) Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. Mandatory flow checks will be performed upon penetration and when tripping out of suspected gas or overpressured zones such as the Campanian, Iceberg, and Bermuda intervals. Lower Shale Stability: Unstable shale and ash in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 2L-316 APD r.„ (\J Page 12 of 14 � Printed: 13-Jan-15 /Dation• for Permit to Drill,Well 2L-316 , Saved: 13-Jan-15 Attachment 3- Proposed Well Schematic Tarn 2L-316 Enterprise Grass Roots lociset,Horizontal Multt-Staoe Prac'd Producer ConocoPhillips Proposed Wellbore Schematic CAMERON . BS 51(math 4,12"hartger/(4.1/16 )Tree „ 16 626H 3't"Cameol DS :+t' Al " . # WITI) 106' ..,_ shue it 1:y•.-:i...n.4 trippla 7 87F' '4", Vir 13-112"Surface Hole 5O31,4D Spud Mud 9.6 PPG '..,1 3'a-'x 1'ktIk16 ,i,t 14 Surface Casino: 10-3i4"45.5#L-Ba Hydril 563 1 2 5.0MD i 2,402'TVD•,,'-ft'l 34 3 Yi'x 1*01130313 le T2514 TVD . „ . . 9418°'Intermediate Hole Tubing: 4..,0wPiiPh6 1W.x"it9/14 WI .. 344 9.3#L80 EUE8RD Daudet% 4-1/2"12.6#L80 IBTM top joint to surface 4 &kenneled tqii nicAment nft c.i.7 MD FAD it,,Orf AVM Wit r.—I 1-P8?l . . . . . . . . . . . . . . . . . . :•:•'•:•:-: :•:•:•:•'-: :-:•:•: : : : : : : ' :•:::•: :•:::::::::,:::,.: II:01er.g:TO 8.5.0'•NIP 14'.*$.7 111.r.)1:. . .:.:H:::: ::::::::::.:::::::::::::::::::::.- .::::•:::::::-:-:•:•:•:-:-. . . . . . . .,. . . . . . . . . . Raker Cu Sliding Sleeve CLOSED*42412.Coma vs.Motile 10'enure Packer —‹?; mrxittowciaton-11.9m MD s ..., 7-5AT,tit3kerPrerrew Packer+/-11,937'MD 1 , r.a-1%-a-,r t4Ippl..2 75' nogo 2=1 I m 1 7-FMK 4-W Deicer Flex Lad.Lirer hanger ZXP liner rep packer 7 T bt,,,,RS taprile,a.G.11,997' Intermediate Casing Topset: ___ 7-5/8"29,7#L-80&bottom 300"TN MSS 39#-all Hydric 563 connections - 6-1/2" Production Hole 'frin a e..iiimk s Venn 1 ' 12,13r MO i 5,356 TVD tr4 80' :•::::::::::::::::::::::::::::::::::::::::: • : : 7-:-:-.1.•.•.•.• • • • ; • • • . .-. • .-•-•-••••:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:• i-::::::::::•••••••••••••**::3q.”.flal.*?,ate!trActers:::•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•: :::•:•:::::::::::::•:•:•:•:•••:•:•:•:•:•:::: ••••:::::::•:•:•:•••••••:•:•:•:•:•• :•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:::::•:::::: :::::::•:•:-:•:•::::.134:16r.A:iii6t,::.:::•:• .• KLASHIE LO i•4:::ifri V..*Y•1-1.52..1.•'•:•••' •••:•••:•:•:•:•:•:: : : : : : : 0 0 0 0 9A.11=0 PPG ::::::.::::::::::::.:.:.:.:.:.:.:... 111 IN. •:,. •:•:•:•••:•:•:•:•:•:::::::::::•::::.... M EL N''-'—wilt :,-:.•:•:•:•:•:•:•:•::::::::.:::::::::::::•:•:•::::::.::::::::::.;................;::::.;.;.;::::::111dijibtakitoA; . ot::::::::::i;:.::.::.....; :•:••:•:•:•:•:• •:•:•:•:•:•:•:•:•:•:•:•.•.•••::‘,1/21.:1240313111:mill.g:tingz::::•:•:•:•:•:•:•. •:•:••••••••:•:Bermuda Pore Pressure •.::::::::::::.•. ::•:•:•:•:•:•:•:•:•:•:•:•:•:•:•11•913ti MO•ii;0,0?0.:Ivo.;:;.;.;.;.;.;.;.;.;.;.; :•:•:•:•••:•:•:::--..8-9.3/9,6-12i 5 ppg •:•:•:•:::•:•:•:• ••••••••••'••••••••••••••••••••••••••:•::::::::::•:•:•tb:•:::•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•: -••••••••:•::::::::: '' ' - -30i'2,7M-3,500 psig) ::::::::::::::::::::::::::::•••• •••••••••• • •••••••:•••••••••:•:•:•:•:::::::::::::: :::::::::•:•:•:•: . . . . . . . . . . . . . .::::::::::::::::•:::::::::::::i1:42969!Mb*),:6:5681W.:::::::::::•:•:•:•:•:•:• .•••••••••••••••• . . . 2L-316 APD Page 13 of 14 „„ RIGINAL Printed: 13-Jan-15 • 4tation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 Attachment 4—Cement Summary 10-3/4" Surface Casing Cement Job Cement 10-3/4" casing from shoe @ 2,510' MD to 2,010' MD (500' of fill)with Class G + Adds @ 15.8 PPG, and from 2,010' to surface with 10.7 PPG Arctic Set Lite. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,408' MD), zero excess in 16" conductor. Lead Slurry: (120') x 0.638 ft3/ft x 1.0 (0% excess) = 77 ft3 (1,408'— 120') x 0.364 ft3/ft x 3.5 (250% excess) = 1641 ft3 above permafrost (2,010'— 1,408)x 0.364 ft3/ft x 1.5 (50% excess) = 329 ft3 below permafrost Total volume= 77 ft3+ 1641 ft3 + 329 ft3= 2047 ft3=> 835 Sx @ 2.45 ft3/sk Lead: 835 Sx Arctic Set Lite @ 10.7 PPG Tail Slurry: (2,510'—2,010') x 0.364 ft3/ft x 1.5 (50% excess) = 273 ft3 annular volume 80' x 0.54 ft3/ft=43.2 ft3 shoe track volume Total volume = 273 ft3 +43.2 ft3= 316.2 ft3 =>271 Sx @ 1.17 ft3/sk Tail: 271 Sx Class G @ 15.8 PPG 7-5/8" Intermediate Casing Cement Job Cement 7-5/8" casing from shoe @ 12,137' MD to 7,600' MD (minimum of 500' above the top of the Iceberg C-37) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. Lead Slurry: (12,137'—7,600') x 0.215 ft3/ft x 1.40 (40% excess) = 1365 ft3 in open hole 80' shoe track x 0.258 ft3/ft x 1.0 (0% excess) = 20.6 ft3 Total volume= 1365 ft3+ 20.6 ft3= 1386 ft3=> 1195 Sx @ 1.16 ft3/sk Total: 1195 Sx Class G @ 15.8 PPG 2L-316 APD Page 14 of 14 OR I G I N L Printed: 13-Jan-15 • 0 PNS 11.. ,• , v : , 3• r mac, .« '' r C 4. ti , -.1 ' N a J , C xi n t.aL I+ 1 U 112 .,0'1"'''V-....1,)b- G{ I ..iS-L Ll L'S • �5 5 �� •L .�fi �y{{ ,j m a v M `., r _ A. i�:• 1 2 5 C:-..'''' . z `1� p '7 mer r Z � R. L. =5�1 t ,¶A,. ),',2,42 t 1„ p i1 lJ,_,./\- .,• r 3,,,21�2L �19H i. 5 4440 x �s'�5 '► a l git am Lf^ i. t. `..t OOC ORIGINAL • faation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 2L-316 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 6 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 7 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 8 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 (Requirements of 20 AAC 25.005 (c)(14)) 9 2L-316 APD Page 1 of 14 GINA Printed. 13-Jan-15 • ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 . 15. Attachment Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Placement and Orientation SUPERSEDED 2L-316 APD 0R I G 1 N A Page 2 of 14 Printed: 13-Jan-15 • illation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2L-316. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. The rig will drill a 13-1/2" surface hole and case with 10-3/4" L-80 with premium connections. The 9-7/8" intermediate section will be drilled to +/- 150' MD above the Bermuda sand, and 7-5/8" top-set casing will be run. A 6-1/2" horizontal production hole will be drilled to TD. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion, with the upper portion being cemented in place using the Bonzai procedure. Finally, a 3-1/2" gaslifted tubing assembly will be run for the upper completion. Location at Surface 188.0' FNL, 733.7' FEL, Sec 22, T10N, R7E, UM NAD 1927 RKB Elevation 153- 142.9' AMSL Northings: 5,927,657.89 Eastings: 460,917.18 Pad Elevation 114.9' AMSL Location at 7 5/8" Intermediate Csg Pt. 2,053.1' FNL, 2,271.1' FEL, Sec 14, T10N, R7E, UM Nad 1927 Measured Depth, RKB: 12,137' Northings: 5,925,567.46 Eastings: 469,931.93 Total Vertical Depth, RKB: 5,356' Total Vertical Depth, SS: 5,203' Location at Top of Productive 2,236.4' FNL, 2025.4' FEL, Sec 24, T10N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 12,448' Northings: 5,925,567.46 Eastings:470,176.92 Total Vertical Depth, RKB: 5,406' Total Vertical Depth, SS: 5,249' Location at Total Depth 4,536.4' FNL, 990.4' FEL, Sec 24, T10N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 14,990' Northings: 5,923,263,68 Eastings: 471,203.34 Total Vertical Depth, RKB: 5,509' Total Vertical Depth, SS: 5,351' 2L-316 APD Page 3 of 14 Printed: 13-Jan-15 ORIGINAL Action for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP (in) MD/TVD(ft) (lbs. /gal) (psi) Drilling (psi) 16 120/ 120 10.9 55 68 10-3/4 2,509/2,402 14.5 1,040 1,462 7-5/8 12,137/5,356 15 2,427 2,260 4-1/2 14,990/ 5,508 15 2,800 2,260 • NOTE: The Doyon 25, 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)— 0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 120' = 68 psi OR ASP = FPP—(0.1 x D) =1,040—(0.1 x 2,402') = 800 psi 2L-316 APD Page 4 of 14 O R I G I N A L Printed: 13-Jan-15 fkation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2,402' = 1,571 psi OR ASP = FPP—(0.1 x D) =2,427—(0.1 x 5,220') = 1,905 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1] x 5,356' = 3,642 psi OR ASP = FPP— (0.1 x D) ✓=2,800—(0.1 x 5,508') = 2,249 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; The most recent SBHPs from offset wells producing wells are: 2L-312: 2,356 psig; 2L-307: 2,650 psig; 2L-306: 1,156 psig; 2L-311: 1,864 psig; The most recent SBHPs for the offset injection wells are: 2L-310: 1,534 psig; and 2L-305: 4,314 psig. Prior to drilling well 2L-316, further offset well pressure surveillance will occur and offset injectors may be shut-in to manage pattern pressures. The Tarn reservoir model predicts the 2L-316 will find reservoir pressure at or near original reservoir pressure of 2,000 to 2,400 psig at the heel of the well with the potential for higher or lower pressure as it is drilled closer to the higher pressured offset injectors and depleted producers. The upper limit of reservoir pressure is estimated at 2,800 psig, but continued pressure monitoring will occur prior to spudding well 2L-316. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 2L-316 APD Page 5 of 14 G I N A L Printed: 13-Jan-15 /Illation for Permit to Drill,Well 2L-316 Saved: 14-Jan-15 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 21-316 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Grade Conn. Length MD/TVD MDJTVD Cement Program OD(in) . _ (in) - (Ib/ft) ... „... (ft) (ft) - (ft) 16 20" 62.5# HW Welded 80' Surf 120'/120' Existing H dril Planned:Cement to Surface with 101/2" 131/2" 45.5# L-80 563 2,470' Surf 2,510'/2,402' 1,060 sx LiteCRETE 11ppg&194 sx 12 ppg LiteCRETE Hydril 7%" 91/2" 29.7# L-80 563 11,798' Surf 11,837'/5,304' Planned:Cement Top planned @ 7,537' MD with 1200 sx 15.8 ppg Class G 7%" 9%8" 39# TN110SS H56311 300' 11,837' 12,137'/5,356' 41/2" 61/2" 12.6# L-80 Hydril 312' 11,987' 12,299'/5,383' 521 Liner Hanger 4'/:" 6%" 12.6# L-80 IBTM 2,691' 12,299' 14,990'/5,508' Swell packers&frac sleeves 41/2" 12.6# L-80 IBTM "30' Surf "30'/30' top 1 jt of tubing 3/" 9.3# L-80 EUE8RM ^'11,987' "30' 11,987' Tubing with Premier Packer Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 7-5/8" 39 TN- 3 Hyd563 10,370 psi 8,296 psi 11,480 psi 9,184 psi 110 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 25. 2L-316 APD Page 6 of 14 OR I G I N A L Printed: 14-Jan-15 • i.ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.5 - 10 ppg 9.6— 10.0 ppg 10.0- 11.0 ppg YP 60 -80 18-28 18 -28 Funnel Viscosity (sec) 75—250 40-55 45 - 55 PV 20 -60 20-25 20-25 Initial Gels 10 -35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.5 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight above 9.5 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. Production Hole Section: KLASHIELD water-based polymer mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 2L-316 APD Page 7 of 14 O R I G I * t A L Printed: 13-Jan-15 111/ 1ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 25 on 2L-316 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface casing point(2,510' MD/2,402' TVD) according to the directional plan. Run MWD/ LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5# L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole to 12,137' MD/5,356' TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)Iwith on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to 12,137' MD/5,356' TVD and cement in place with a minimum of 500' of o- cement above the Iceberg formation. 13. MU 6-1/2" bit and BHA, RIH on 4" drill pipe. 14. Drill the 6-1/2" production hole to 14,990' MD /5,508' TVD as per directional program. 15. POOH, and run 4 1/2" production liner complete with swell packers and frac sleeves. 16. Place liner hanger on depth, pressure up and set hanger, continue to pressure up and release liner hanger from running tool, POOH with running tool while laying down drill pipe. 17. Run 3-1/2" completion tubing with premier packer and seals and set packer at+/- 12,000' MD/5,333' TVD. 18. Bleed of pressure in tubing and pressure up annulus to shear out lower GLM 19. Change well over to KW brine, install BPV 20. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 2L-316 APD Page 8 of 14 1) RIGINAL Printed: 13-Jan-15 /ation for Permit to Drill,Well 2L-316 Saved: 13-Jan-15 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Placement and Orientation 2L-316 APD Page 9 of 14 JRIGINAL Printed: 13-Jan-15 I ! Loepp, Victoria T (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Thursday, February 05, 2015 11:39 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-316(PTD 215-006) Attachments: 2L-316 Permit to Drill.doc; Diverter for 2L-316.pdf Victoria, Unfortunately, in my haste to get this permit out, it looks as though I totally botched it. In response to you inquiries: 1) I have corrected the cement volumes,the calculations in the back are correct but I forgot to put those in the body of the document. 2) I have attached a diverter diagram 3) This is not to be a Bonzai (cut and paste error) 4) I have gone through the calculations for the "anticipated surface pressure section" and corrected same. The original permit I submitted included a 4'A"casing which I have excluded (again cut and paste error) 5) I have placed all the changes in red in the document I apologize for the confusion and my inattentiveness for QA/QC. Steve From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 03, 2015 2:54 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 2L-316(PTD 215-006) Steve, 1. The surface casing cementing calculations don't agree with the number of sacks stated on the Permit application Need to know which is correct. 2. Please provide a diverter route schematic 3. In the summary,you mention a Bonzai completion which this well doesn't have. 4. The pressure summary table in the Drilling Hazards Section(pg4)don't agree with the following calculations. Would your maximum surface pressure be 2800 psi and the max reservoir pressure2800 psi? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.nov 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 1 • • ti, S7 2, 2G1. � c ` , :0'j i . 2\ 7 .•i52�\' Y` tS ,. •r -1 'f- 4tit _= J l ` 4a , 7' • ' •,-, ,, 101/A h ' \,•:: r r,7 1-.4: FY N --J • LV • : ; `A`-~ • Y a T / \ '1 ...,c .412 il' .l1``'• #ir , qi x',9- M • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Monday,January 26, 2015 4:29 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2L-316: Permit to Drill Application Patricia, Sorry I didn't get right back to you, I was on holiday. We ran the GR/RES/Neut/Dens, Periscope and SonicScope. Steve From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, January 23, 2015 4:33 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]FW: KRU 2L-316: Permit to Drill Application Good afternoon Steve, Any news on what logs are going to be run in the 6%2" production hole? From: Bettis, Patricia K (DOA) Sent: Tuesday, January 20, 2015 9:45 AM To: Shultz, Steve (Orbis Engineering, Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 2L-316: Permit to Drill Application Good morning Steve, What logs are planned to be run in the 61/2" production hole? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, January 20, 2015 9:45 AM To: Shultz, Steve (Orbic Engineering, Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 2L-316: Permit to Drill Application Good morning Steve, What logs are planned to be run in the 61/2" production hole? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 ! • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Friday,January 16, 2015 11:23 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2L-316: PERMIT TO DRILL APPLICATION Patricia, The figure on page 3 of the application is in error. That figure was using the KB from Doyon 141 and this well is to be drilled with Doyon 25. The 157' figure is correct. Sorry about the confusion. Steve Shultz Engineering Consultant ConocoPhillips 263-4297 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, January 16, 2015 11:04 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 2L-316: PERMIT TO DRILL APPLICATION Good morning Steve, Form 10-401, Box 10, states the KB for the proposed KRU 2L-316 to be 157 feet. The height of 157 feet is also provided in the heading of the proposed wellbore survey. On page 3 of the Application for Permit to Drill Document,the KB is shown as 142.9 feet. Please verify which elevation is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 I -- • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, January 16, 2015 11:04 AM To: Shultz, Steve (Orbis Engineering,Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 2L-316: PERMIT TO DRILL APPLICATION Good morning Steve, Form 10-401, Box 10, states the KB for the proposed KRU 2L-316 to be 157 feet. The height of 157 feet is also provided in the heading of the proposed wellbore survey. On page 3 of the Application for Permit to Drill Document,the KB is shown as 142.9 feet. Please verify which elevation is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K/P,t,., ,91.-31‘ PTD: 4i S - 00 co /Development _Service _Exploratory _Stratigraphic Test Non-Conventional FIELD: kvtieckeuft. P,{VEr POOL: CfrAixAjeN RIV6ir f' aen ®i/ f Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging in also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, / composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 • 0 _J' N m Q N N a) 0 u' o `° a) -5c Q �� a L m. a) -o, a v, > _c wa . In O t 0' z a`) 3 Gi c w ca a) 3' a 3' 0 oc co o w. y a) Z c. 3. ° 4 o oo c ami o 0 a ° n • I-' "c7)" P. g, 11 o El2 on -6 Z C' c> -- EO' N. a ' a) •0 c N' r� 0) N, J• J, M �� 1:5 co m, N, 1), O U' 2 a)' t, v. o m Y ) a, .NE .o , E, N , > O « a) D. a), 2 N j C 0,vr a c 0 1 Z M, N. 0. 7. U. N ° @ °0 0- O E �' > O a E' a .) a� 0 0 W; D' 0 !' o = L0 2, o c� 0, ( 13- c'a N'� x c Z Q Y Y. (•) 5 U v) , a, , i < Q . g. 2. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of inforination. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: May 3, 2015 Surface Data Logging End of Well Report 2L-316 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Rig: Doyon 25 Well: 2L-316 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20704-00-00 Sperry Job Number: AK-AM-0902329981 Job Start Date: 14 April 2015 Spud Date: 11 April 2015 Total Depth: 14990’ MD, 5521’ TVD North Reference: True Declination: 18.784° Dip Angle: 80.784° Total Field Strength: 57541.091 nT Date Of Magnetic Data: 01 April 2015 Wellhead Coordinates N: North 70° 12’ 46.763” Wellhead Coordinates W: West 150° 19’ 5.860“ Drill Floor Elevation 154.71’ Ground Elevation: 114.90’ Permanent Datum: Mean Sea Level SDL Engineers: Macy Williams, Elijah Callan SDL Sample Catchers: Geoff Yenter, Will Halliburton, Kruz Kleewein Company Geologist: Kristin Hannon, Brett Harvey Company Representatives: Granville Rizek, Don Mickey, Paul Smith, Lee Martin, Rob Rehinhardt SSDS Unit Number: 125 DAILY SUMMARY 04/14/2015 SDL arrive on location. Finish drilling surface to 2528' MD. Circulate and monitor well. Begin pulling out of hole. 04/15/2015 Pick up and begin running in hole with 10.75" casing to 2518' MD. Rig up cementers and pump cement. SDL rigging up unit and equipment. 04/16/2015 Nipple up BOP and complete BOP test. Complete test of MPD chokes. Rig down testing equipment. Cut and slip drill line. Rig up for casing test. 04/17/2015 Complete casing test. Drilled through cement from 2384' MD to 2516' MD at top of shoe. Continue drilling to intermediate hole to 2548' MD. Circulate bottoms up, pumped 65 bbls Hi-vis pill and displaced DrilPlex to LSND mud. Performed FIT test. Continue drilling ahead. Gas: The max gas was 70 units at 2696’ MD and the average drilling background gas was 30 units. Fluids: There were 39 bbls loss down hole. Geology: The samples have been predominantly Claystone, light grey to dark grey, gummy to very soft, amorphous to plastic, moderately silty throughout, slightly calcareous with a good trace of pyrite. 04/18/2015 Continue drilling 9 7/8" intermediate hole from 3282' MD. Pumped hi vis sweep #2 at 3400' MD with 75% increase in cuttings. Pump hi vis sweep #3 at 4000' MD with 30% increase in cuttings. Removed trip nipple and installed MPD bearing. Pumped hi vis sweep #4 at 4510' MD with 15% increase in cuttings. Pumped hi vis sweep #5 at 5006'' MD with 10% increase in cuttings. Continue drilling ahead. Gas: The max gas was 59 units at 4310‘ MD and the average drilling background gas was 35 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone, medium grey to dark grey, slightly firm to slightly hard, subblocky to blocky, moderately silty throughout, slightly arenaceous, slightly calcareous cement with a slight trace of glauconite and tuff. 04/19/2015 Continued drilling 9 7/8" intermediate hole from 5504' to 7358'. Performed dump and dilution at 15:30. At 21:30 the top drive required service and is currently being diagnosed and serviced. Currently circulating the hole while servicing the top drive. Continue drilling ahead from 7358’ MD. Gas: The max gas was 122 units at 7356‘ MD and the average drilling background gas was 50 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone, light to medium brown, soft to moderately hard, mushy in places, moderately indurated, brittle to crumbly, silty to gritty texture, massive to blocky cuttings. 04/20/2015 Coninued to circulate at 450 gpm while servicing the top drive. Top drive was repaired. Continue to drill 9 7/8" intermediate hole from 7358'. Began to use MPD system starting at 7935'. Experienced high return flow at 9102', with a max gas of 552 units. Continue drilling ahead through intermediate section. Gas: The max gas was 552 units at 9066‘ MD and the average drilling background gas was 120 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Sandstone, light to medium gray, fine to medium grain, subrounded to well rounded, very well sorted, unconsolidated, predominately translucent to opaque loose quartz, with calcite and biotite in places. 04/21/2015 Continue drilling ahead through intermediate section. Gas: The max gas was 361 units at 11421‘ MD and the average drilling background gas was 178 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Sandstone, light gray to gray white, fine to medium grain, subrounded to well rounded, very well sort, unconsolidated, predominately translucent to opaque loose quartz, with calcite and occasional biotite in places. 04/22/2015 TD the Intermediate hole at 12197' MD. Circulate 3 bottoms up. Then begin back reeming out of the hole. Mud Logger unit rig down temporarily. Gas: The max gas was 219 units at 12197‘ MD and the average drilling background gas was 160 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone, light to dark gray, very soft to moderately hard, moderately indurated, brittle to crumbly, massive to flakey cuttings, and a silty to gritty texture. 04/23/2015 Finish back reeming out of the hole. Lay down BHA and rig up for casing run. Begin running in hole with 7.625” casing. Mud Logger unit rigged down temporarily. Gas: No significant gas data. Fluids: There were no losses down hole. 04/24/2015 Finish running in the hole with 7.625” casing. Circulate and condition mud. Mud Logger Unit rigged down temporarily. Gas: No significant gas data. Fluids: There were no losses down hole. 04/25/2015 Pump cement per Sclumberger program. Rig down equipment. Begin Laying down 5” drill pipe and picking up 4” drill pipe. Mud Logger Unit rigged down temporarily. Gas: No significant gas data. Fluids: There were 42 bbl losses down hole. 04/26/2015 Finish picking up 4” drill pipe, building stands, and stand back. BOPE test and begin making up BHA. Begin tripping in hole to 3519’ MD. Troubleshoot draw works. Gas: No significant gas data. Fluids: There were no losses down hole. 04/27/2015 Draw works are back online. Test casing and continue running in hole with 4" drill pipe singles. Gas: No significant gas data. Fluids: There were no losses down hole. 04/28/2015 Tagged top of casing at 12501' MD. Drilled through the shoe plus 20' to 12217' MD. Circulated bottoms up conditioning mud until weighted to 9.8ppg in/out. Performed FIT with a result of 16. Pumped 74 bbls of Hi-vis spacer and displaced hole from LSND to Kla-Shield mud. Installed MPD bearing. Drilling ahead 6.5" production hole. Gas: The max gas was 51 units at 14361‘ MD and the average drilling background gas was 35 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone, light to medium gray, soft to moderately firm, some friable, brittle to crumbly, massive to platy cuttings, dull luster, and a silty to gritty texture. 04/29/2015 Drilled ahead through the production section. Gas: The max gas was 3105 units at 12459‘ MD and the average drilling background gas was 487 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Sandstone, light gray to gray white, fine to coarse grain, subrounded to round, moderately to well sort, predominately well consolidated, slightly calcareous in places, some quartz inclusions, 60% yellow fluorescence, fast weak streaming cut. 04/30/2015 Finish Production section. Gas: No significant gas data. Fluids: There were no losses down hole. 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 5 10 15 20 25 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2L-316 (Enterprise) OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0902329981 Days vs. Depth 14 April 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 11-Apr-2015 TD: 30-Apr-2015 Landed 7.625" Casing 12187' MD, 5366' TVD 24 Apr 2015 Commenced 9.725" Intermediate Hole Section On Bot: 07:20 17 April 2015 TD Intermediate Hole Section 12197' MD, 5368' TVD Off Bot: 02:45 22 April 2015 Commenced 6.5" Production Hole Section On Bot: 07:30 28 April 2015 TD Production Hole Section 14990' MD, 5521' TVD Off Bot: 00:30 30 April 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: After cleaning out a drop out jar, the black o-ring that seals the container had accidently fell out. This was causing a leak in the system and the sample line would not pressurize. Recommendations: If sample pressure will not pressurize, first easy check is the o-ring in the drop out jar. Kinks or no o- ring at all could be the cause. Innovations and/or cost savings: N/A Doyon 25 Macy Williams Kuparuk River Unit North Slope Borough Alaska Intermediate 27-Apr-2015 What went as, or better than, planned: The CVE system is working well and easy to maintain. 2L-316 (Enterprise) ConocoPhillips Alaska, Inc. AK-XX-0902329981 Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The CPI fitting connecting the suction assembly head to the 1" tubing was not tight enough causing there to be a leak in the system. Recommendations: If there is anything loose within the entire suction assembly it will affect the amount of suction and could cause low/no gas readings. When the CPI fitting is tighten properly, there shouldn't be any movement in the head piece. Innovations and/or cost savings: N/A What went as, or better than, planned: The CVE system is working well and has been properly maintained throughout the section. 2L-316 (Enterprise) ConocoPhillips Alaska, Inc. AK-XX-0902329981 Doyon 25 Macy Williams Kuparuk River Unit North Slope Borough Alaska Production 30-Apr-2015 Surface Data Logging After Action Review 2L-316 (Enterprise) ConocoPhillips Alaska, Inc. Mi Swaco Doyon 25 AK-XX-0902329981 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 16-Apr 2528 9.70 50 9 26 6/8/9 6.0 44/35/29/21/7/6 1/-6.0 1/93 0.00 1.00 9.7 2.5 .70/1.98 600 20 Casing Test 17-Apr 3283 9.60 47 9 30 10/11/12 5.2 48/39/33/25/11/10 1/-6.0 2/92 0.20 0.85 9.8 7.5 .30/1.70 800 60 Drilling ahead 18-Apr 5494 9.60 48 13 24 7/9/11 4.2 50/37/30/24/9/7 1/-7.0 3/90 0.25 0.80 10.0 12.5 .60/1.50 600 100 Drilling ahead 19-Apr 7358 9.70 52 22 25 11/13/16 4.2 69/47/39/29/13/12 1/-7.0 2/91 tr 0.85 9.9 17.5 .40/.80 400 120 Circulating Hole 20-Apr 9263 9.70 45 12 26 9/10/11 3.9 50/38/31/2510/9 1/-9.0 3/89 1.00 0.70 9.9 20.0 .40/1.10 300 160 Drilling ahead 21-Apr 12008 9.80 45 11 20 6/7/8 3.8 42/3125/19/8/6 1/-9.0 3/88 0.50 0.50 10.0 22.5 .35/1.10 300 160 Drilling ahead 22-Apr 12197 9.80 48 11 23 7/8/9 3.8 45/34/29/22/8/7 1/-9.0 3/88 0.50 0.40 9.9 20.0 .32/1.10 300 160 Circulate Bottoms Up 23-Apr 12197 9.70 44 14 23 8/9/10 4.0 51/37/30/23/9/8 1/-9.0 3/88 0.25 0.35 9.9 20.0 .20/1.10 300 160 RIH Casing 24-Apr 12197 9.80 52 17 22 9/11/12 4.0 56/39/33/24/10/9 1/-9.0 3/88 0.25 0.40 9.9 22.5 .32/1.10 300 160 Circulating Mud 25-Apr 12197 9.80 40 10 17 6/7/7 -37/28/23/18/7/6 1/-8.0 1/91 0.25 0.35 8.8 22.5 .30/1.00 300 160 P/U 4" Drill Pipe 26-Apr 12197 9.80 40 9 19 6/7/7 -37/28/22/17/7/6 1/-8.0 1/91 0.25 0.32 8.8 22.5 .22/1.00 300 160 Inspect Drawworks 27-Apr 12197 9.80 41 10 18 6/7/8 -38/28/22/17/7/6 1/-8.0 1/91 0.25 0.30 8.8 22.5 .22/1.00 300 160 SIH 4" Drill Pipe 28-Apr 12501 9.80 45 10 15 5/6/6 3.9 35/25/21/15/6/5 1/1 8.0 2/90 0.75 5.40 10.0 0.6 7.00/6.90 95000 400 Drilling ahead 29-Apr 14927 9.90 48 11 19 5/6/6 4.1 41/30/24/19/6/5 1/1 8.0 2/90 0.50 5.50 10.2 1.3 5.20/10.00 92500 400 Drilling to TD 30-Apr 14990 10.00 48 10 19 5/6/7 4.2 39/29/23/18/6/5 1/1 8.0 2/90 0.50 5.60 10.2 1.3 5.00/9.90 95000 400 Stand back HW 1-May 14990 10.00 48 9 21 5/6/8 4.1 39/30/24/19 1/2 8.0 0.0 0.50 5.30 10.1 1.3 4.60/9.80 95000 400 RIH 4.5" Liner Casing Record Remarks 10.75" Casing @ 2518' MD,2518' TVD 7.625" Casing @ 12187' MD, 5366'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:11-Apr-2015 SPERRY JOB:TD:30-Apr-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 3 100 3 Reed Hycalog PDC 9.88 2528 12197 9669 75.75 0.990 128.8 12K 160 3220 700 1-2-CT-S-X-I-CTTD TD Intermediate Hole Section 4 200 4 Reed Hycalog PDC 6.50 12197 14990 2793 20.72 0.383 137.0 10K 150 2680 254 1-1-CT-G-X-I-NOTD TD Production Hole Section WELL NAME:2L-316 (Enterprise)LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902329981 TD:30-Apr-2015 MI Swaco STATE:Alaska RIG:Doyon 25 SPUD:11-Apr-2015 B i t R e c o r d . . * 24 hr Recap:Finished nippling up BOP and completed BOPE test. Completed test of MPD chokes. Rigged down testing rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 16-Apr-2015 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 6.09.7+9.7+ Size Tagged top of casing 2384'. Rigged up for casing test. 2518' 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Type DRILPLEX 6.02528'26 Depth in / out YP (lb/100ft2) 9.70 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Preparing to drill out casing shoe PV Footage Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 9 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 2528' 2528' 0' Max @ ft Current 0'0.0 Date: Time: equipment. Picked up BHA and ran in hole per DD and MWD. Cut and slipped drill line. Washed down from 2262' MD to 2384' MD. in Minimum Depth C-5n 0.0 C-2 SPP (psi) Gallons/stroke TFABit Type Depth 2.550 MBT pH Siltst 0 0 Units* Casing Summary Lithology (%) (907)-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Williams Set AtSize 45.5 Grade 10.75" (max)(current) Cly Bottoms Up Time 169.1 0 1681204.74 35.64 16 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Completed casing test. Drilled through cement from 2384' MD to 2516' MD at top of shoe. Continue drilling to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 0 17-Apr-2015 12:00 AM Current Pump & Flow Data: 1725 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.24 Doyon 25 Report For: ConditionBit # 2 6.0 9.875 9.70 PDC 9.6+ Size 40 bbls Hi-vis sweep @ 3017' MD, saw 50% increase in cuttings returned. Drilling ahead. 2518' 100% Gas In Air=10,000 UnitsConnection 75 0 Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 26.22528' 3283' WOB Surface 8.2210.25 Avg Min Comments RPM ECD (ppg) ml/30min 25Background (max) Trip Average Mud Type Lst 10% Type 73.3 LSND 5.23283'30 Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Drilling Ahead PV 755' Footage 8.83 Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 9 Gas Summary 0 0 0 (current) Avg to2528' Yesterday's Depth: Current Depth: 24 Hour Progress: 116.0 Flow In (gpm) Flow In (spm) 2528' 3282' 752' Max @ ft Current 3241'79.0 Date: Time: intermediate hole +20' at 2548' MD. CBU, pumped 65 bbls Hi-vis pill and displaced DrilPlex to LSND. Performed FIT test. Pumped 13 in 0 2528'Minimum Depth C-5n 3009' 115.0 C-2 84 SPP (psi) Gallons/stroke TFABit Type Depth 7.547 MBT 3282' pH 0 0 0 Siltst 698 165 Units* Casing Summary Lithology (%) 0 15% 2614 0 907-659-7599Unit Phone: 0 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Williams Set AtSize 45.5 Grade 10.75" (max)(current) 4 0 Cly 10429 Bottoms Up Time 160.96 0212.42 51.47 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 110.27 7 1800242.16 90.88 10 (max)(current) 70 0 Cly 20912 70% Set AtSize 45.5 Grade 10.75" 907-659-7599Unit Phone: 6 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams 4429 32 702 165 Units* Casing Summary Lithology (%) 0 MBT 5502' pH 0.991 0 14 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.548 C-5n 4310' 117.0 C-2 59 in 1 3760'Minimum Depth Time: cuttings. Pump hi vis sweep #3 at 4000' MD with 30% increase in cuttings. Removed trip nipple and installed MPD bearing. 27 3282' 5502' 2220' Max @ ft Current 4975'134.0 Date: Avg to3282' Yesterday's Depth: Current Depth: 24 Hour Progress: 181.0 Flow In (gpm) Flow In (spm) Gas Summary 0 5 0 (current) Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 13 2220' Footage 25.78 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Drilling Ahead PV 24 hr Max Weight 31 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 000 108.6 LSND 4.25494'24 Depth in / out Mud Type Lst 30% Type Average 35Background (max) Trip 8.8010.60 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 13.82528' WOB Surface 100% Gas In Air=10,000 UnitsConnection 12 cuttings. Continue drilling ahead. Pumped hi vis sweep #4 at 4510' MD with 15% increase in cuttings. Pumped hi vis sweep #5 at 5006'' MD with 10% increase in 2518' ConditionBit # 2 7.0 9.875 9.75 PDC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.80 Doyon 25 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Apr-2015 12:00 AM Current Pump & Flow Data: 2547 Max 3 Chlorides mg/l 600.00 Continue drilling 9 7/8" intermediate hole from 3282' MD. Pumped hi vis sweep #2 at 3400' MD with 75% increase in rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling 9 7/8" intermediate hole from 5504' to 7358'. Performed dump and dilution at 15:30. At 21:30 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 56 19-Apr-2015 12:00 AM Current Pump & Flow Data: 1384 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.62 Doyon 25 Report For: ConditionBit # 2 7.0 9.875 9.70 PDC 9.70 Size top drive. 2518' 100% Gas In Air=10,000 UnitsConnection 261 Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 21.92528' WOB Surface 10.5411.21 Avg Min Comments RPM ECD (ppg) ml/30min 11Background (max) Trip Average Mud Type Lst 10% Type 156.0 LSND 4.27358'25 Depth in / out YP (lb/100ft2) 9.90 6153 00 CementChtSilt C-4i C-4n 24 hr Max Weight 172 Hours C-3 20 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Troubleshooting Top Drive PV 7317' Footage 59.10 Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 22 Gas Summary 0 67 19 (current) Avg to5502' Yesterday's Depth: Current Depth: 24 Hour Progress: 186.0 Flow In (gpm) Flow In (spm) 5502' 7358' 1856' Max @ ft Current 5755'79.4 Date: Time: the top drive required service and is currently being diagnosed and serviced. Currently circulating the hole while servicing the 50 in 5 5561'Minimum Depth C-5n 7356' 0.0 C-2 122 SPP (psi) Gallons/stroke TFABit Type Depth 17.552 MBT 7358' pH 0 50 0 Siltst 452 107 Units* Casing Summary Lithology (%) 16 70% 6403 175 907-659-7599Unit Phone: 30 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) 672 0 Cly 14777 Bottoms Up Time 67.9 33 1833242.16 123.83 17 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Coninued to circulate at 450 gpm while servicing the top drive. Top drive was repaired. Continue to drill 9 7/8" Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 40/1.1 369 20-Apr-2015 12:00 AM Current Pump & Flow Data: 2893 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.40 Doyon 25 Report For: ConditionBit # 2 9.0 9.875 9.85 PDC 9.75 Size of 552 units. Continue drilling ahead through intermediate section. 2518' 100% Gas In Air=10,000 Units552Connection 990 Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 9.02528' WOB Surface 10.7711.25 Avg Min Comments RPM ECD (ppg) ml/30min 102Background (max) Trip Average Mud Type Lst 90% Type 161.0 LSND 3.98980'26 Depth in / out YP (lb/100ft2) 9.90 2810470 00 CementChtSilt C-4i C-4n 24 hr Max Weight 700 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Drilling ahead PV 9270' Footage 72.40 Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 12 Gas Summary 0 271 29 (current) Avg to7358' Yesterday's Depth: Current Depth: 24 Hour Progress: 206.0 Flow In (gpm) Flow In (spm) 7358' 9263' 1905' Max @ ft Current 9199'150.0 Date: Time: intermediate hole from 7358'. Began to use MPD system starting at 7935'. Experienced high return flow at 9102', with a max gas 118 in 3 7357'Minimum Depth C-5n 9066' 160.0 C-2 552 SPP (psi) Gallons/stroke TFABit Type Depth 20.045 MBT 9263' pH 6 174 0 Siltst 698 164 Units* Casing Summary Lithology (%) 65 10% 12438 295 907-659-7599Unit Phone: 80 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) 2030 10 Cly 53438 Bottoms Up Time 663.21 0 6585881.02 157.68 40 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Drilling ahead from 9263' through intermediate section. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 300.00 516 21-Apr-2015 12:00 AM Current Pump & Flow Data: 3088 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.41 Doyon 25 Report For: ConditionBit # 2 9.0 9.875 10.00 PDC 9.80 Size 2518' 100% Gas In Air=10,000 Units163Connection 1588 Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 8.02528' 12196' WOB Surface 10.9411.20 Avg Min Comments RPM ECD (ppg) ml/30min 178Background (max) Trip Average Mud Type Lst 20% Type 160.0 LSND 3.811670'20 Depth in / out YP (lb/100ft2) 10.00 7424555 00 CementChtSilt C-4i C-4n 24 hr Max Weight 780 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Drilling ahead PV 9668' Footage 91.80 Granville Rizek/Don Mickey ShClyst TuffGvlCoal cP 11 Gas Summary 0 665 152 (current) Avg to9263' Yesterday's Depth: Current Depth: 24 Hour Progress: 210.0 Flow In (gpm) Flow In (spm) 9263' 12005' 2742' Max @ ft Current 11558'160.0 Date: Time: 113 in 8 9172'Minimum Depth C-5n 11421' 122.0 C-2 361 SPP (psi) Gallons/stroke TFABit Type Depth 22.545 MBT 12005' pH 13 207 0 Siltst 500 172 Units* Casing Summary Lithology (%) 76 80% 32613 253 907-659-7599Unit Phone: 194 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) 2813 19 Cly 32613 Bottoms Up Time 860.4 0 85001140.86 206.4 65 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 860 0 86001145210 65 (max)(current) 1770 12 Cly 17192 Set AtSize 45.5 Grade 10.75" 907-659-7599Unit Phone: 194 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams 60% 7784 230 702 166 Units* Casing Summary Lithology (%) 207 MBT 12197' pH 7 113 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.048 C-5n 12197' 0.0 C-2 219 in 2 11903'Minimum Depth Time: Back reamed out of hole to 4340' MD. Pulled out of hole on elevators to shoe. 108 12005' 12197' 192' Max @ ft Current 12092'126.0 Date: Avg to12005' Yesterday's Depth: Current Depth: 24 Hour Progress: 160.0 Flow In (gpm) Flow In (spm) Gas Summary 0 705 160 (current) Lee Martin/Don Mickey ShClyst TuffGvlCoal cP 11 9669' Footage 91.80 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 POOH PV 24 hr Max Weight 797 Hours C-3 30 05 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 11338891 160.0 LSND 3.812197'23 Depth in / out Mud Type Lst 10% Type Average 160Background (max) Trip 10.5911.34 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 8.02528' 12197' WOB Surface 100% Gas In Air=10,000 UnitsConnection 1359 2518' Condition 1,2,CT,S,X,1,CT,TD Bit # 2 9.0 9.875 9.70 PDC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.45 Doyon 25 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Apr-2015 12:00 AM Current Pump & Flow Data: Max 683 Chlorides mg/l 300.00 Intermediate hole TD at 12,197' MD. Pumped 40bbls of Hi-Vis sweep and circulated bottoms up 3 times. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Pulled out of hole on elevators. Layed down BHA. Make dummy run with hanger on landing joint. Cganged top rams Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 23-Apr-2015 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 9.875PDC Size 4362' MD. 2518' 100% Gas In Air=10,000 UnitsConnection Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 2528' 12197' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Depth in / out YP (lb/100ft2) CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 RIH w/ Casing PV 9669' Footage 91.80 Lee Martin/Don Mickey ShClyst TuffGvlCoal cP Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 12197' 12197' 0' Max @ ft Current Date: Time: to 7 5/8", test. Rigged up Volant CRT with swivel for cementing. Ran in hole with 7 5/8" casing. Circulated at 2486' MD and at in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth MBT pH Siltst Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max)(current) Cly Set AtSize 45.5 Grade 10.75" 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 in Minimum Depth Time: 12197' 12197' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Lee Martin/Don Mickey ShClyst TuffGvlCoal cP 9669' Footage 91.80 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Circulating PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 2528' 12197' WOB Surface 100% Gas In Air=10,000 UnitsConnection 2518' Condition 1,2,CT,S,X,1,CT,TD Bit # 2 9.875PDC Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Apr-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l Finished running in hole with 7 5/8" casing. Circulating and conditioning mud. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Pumped cement per Schlumberger program. Rigged down eqipment. Pumped ISOTHERM NT down open Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 25-Apr-2015 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 9.875PDC Size 2518' 100% Gas In Air=10,000 UnitsConnection Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 2528' 12197' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Depth in / out YP (lb/100ft2) CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 PU 4" DP PV 9669' Footage 91.80 Lee Martin/Don Mickey ShClyst TuffGvlCoal cP Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 12197' 12197' 0' Max @ ft Current Date: Time: annulus. Laid down 5" drill pipe. Picking up 4" drill pipe. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth MBT pH Siltst Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max)(current) Intermediate Cly Set AtSize 45.5 Grade 10.75" 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams 7.625" Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 in Minimum Depth Time: Make up BHA. Single in hole with 4" drill pipe. Troubleshooting drawworks. 12197' 12197' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Lee Martin/Don Mickey ShClyst TuffGvlCoal cP 9669' Footage 91.80 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Troubleshooting Drawworks PV 24 hr Max 29.7 Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma Resistivity and ECD API FL Chromatograph (ppm) 2528' 12197' WOB Surface 100% Gas In Air=10,000 UnitsConnection 12197' 2518' Condition 1,2,CT,S,X,1,CT,TD Bit # 2 9.875PDC Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 26-Apr-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l Finish picking up 4" drill pipe, build stands and stand back. Clean out seaver sub. Pick up BHA. Test BOPE. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max)(current) Intermediate Cly Set AtSize 45.5 Grade 10.75" 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams 7.625" Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.541 C-5nC-2 in Minimum Depth Time: 12197' 12197' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Lee Martin/Don Mickey ShClyst TuffGvlCoal cP 10 9669' Footage 91.80 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Single in hole 4" DP PV 24 hr Max 29.7 Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.80LSND4.212197'18 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 2528' 12197' WOB Surface 100% Gas In Air=10,000 UnitsConnection 12187' 2518' Condition 1,2,CT,S,X,1,CT,TD Bit # 2 8.0 9.875 9.80 PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Apr-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 300.00 Draw works are back online. Test casing and continue running in hole with 4" drill pipe singles. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Tagged top of casing at 12501' MD. Drilled through the shoe plus 20' to 12217' MD. Circulated bottoms up Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 95000.00 82 28-Apr-2015 12:00 AM Current Pump & Flow Data: 2245 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.17 Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 8.0 9.875 9.80 PDC 9.80 Size 3 LSND to Kla-Shield. Installed RCD bearing. Drilling ahead 6.5" production hole. 12187' 2518' 100% Gas In Air=10,000 UnitsConnection 147 Tools Gamma and Resistivity API FL Chromatograph (ppm) 2528' 12197' WOB Surface 10.7210.89 Avg Min Comments RPM ECD (ppg) ml/30min 35Background (max) Trip Average Mud Type Lst Type PDC Kla-Shield 15.0 12197' 12501'10 Depth in / out YP (lb/100ft2) 10.00 0260 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 137 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Drilling ahead PV 9669' 6.5 Footage 5.38 326' 91.80 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP Gas Summary 0 46 0 (current) Avg to12197' Yesterday's Depth: Current Depth: 24 Hour Progress: 130.0 Flow In (gpm) Flow In (spm) 12197' 12509' 312' Max @ ft Current 12490'85.0 Date: Time: conditioning mud until 9.8ppg in/out. Performed FIT with a result of 16.0. Pumped 74 bbls of Hi-vis spacer and displaced hole from 35 in 14 12280'Minimum Depth C-5n 12459' 107.0 C-2 51 SPP (psi) Gallons/stroke TFABit Type Depth 0.645 MBT 12509' pH 0 11 0 Siltst 7.625" 254 60 Units* Casing Summary Lithology (%) 5 100% 1703 99 907-659-7599Unit Phone: 7 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Intermediate 266 0 Cly 3771 Bottoms Up Time 386 0 3844570133 64 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Drilled ahead through the production section. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 92500.00 3321 29-Apr-2015 12:00 AM Current Pump & Flow Data: 2553 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.47 Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 8.0 9.875 9.90 PDC 9.95 Size 3 12187' 2518' 100% Gas In Air=10,000 UnitsConnection 19320 Tools Gamma, Resistivity, Neutron Porosity, ADM, Impulse, Sonic Scope API FL Chromatograph (ppm) 2528' 12197' WOB Surface 10.8011.19 Avg Min Comments RPM ECD (ppg) ml/30min 700Background (max) Trip Average Mud Type Lst 90% Type PDC Kla-Shield 4.1 12197' 14701'19 Depth in / out YP (lb/100ft2) 10.20 6371870457 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 3242 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 TD production section PV 9669' 6.5 0.383 Footage 2429' 91.80 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 Gas Summary 0 10089 2339 (current) Avg to12509' Yesterday's Depth: Current Depth: 24 Hour Progress: 310.0 Flow In (gpm) Flow In (spm) 12509' 14938' 2429' Max @ ft Current 13964'168.0 Date: Time: 487 in 2 12450'Minimum Depth C-5n 14361' 0.0 C-2 3105 SPP (psi) Gallons/stroke TFABit Type Depth 1.348 MBT 14990' pH 0 2770 0 Siltst 7.625" 258 59 Units* Casing Summary Lithology (%) 498 10% 23536 40 907-659-7599Unit Phone: 3184 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Intermediate 22358 0 Cly 171969 Bottoms Up Time 452 0 4337673159 75 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:TD production hole at 14,990' MD. Circulated bottoms up, and evened mud to 10.0ppg in/out. Back reamed out of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 92500.00 508 30-Apr-2015 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.37 Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 8.0 9.875 10.00 PDC 10.00 Size 3 Strip out of hole per MPD schedule. 12187' 2518' 100% Gas In Air=10,000 UnitsConnection 7592 Tools Gamma, Resistivity, Neutron Porosity, ADM, Impulse, Sonic Scope API FL Chromatograph (ppm) 2528' 12197' WOB Surface 11.3511.36 Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Type PDC Kla-Shield 4.2 12197' 14990'19 14990' Depth in / out YP (lb/100ft2) 10.20 315517204 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 421 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 Stand back HWDP PV 9669' 6.5 0.383 Footage 112.50 2429' 91.80 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 10 Gas Summary 0 4393 1144 (current) Avg to14938' Yesterday's Depth: Current Depth: 24 Hour Progress: 210.0 Flow In (gpm) Flow In (spm) 14938' 14990' 52' Max @ ft Current 14971'149.0 Date: Time: hole to 12,183' MD and circulated bottoms up. Pumped 40 bbls of Hi-vis sweep. Monitored well. Pumped 40 bbls dry job. 132 in 8 14759'Minimum Depth C-5n 14982' 0.0 C-2 1298 SPP (psi) Gallons/stroke TFABit Type Depth 1.348 MBT 14990' pH 0 1154 0 Siltst 7.625" 0 0 Units* Casing Summary Lithology (%) 11543024 28 907-659-7599Unit Phone: 1613 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Intermediate 7827 0 Cly 59870 Bottoms Up Time 673 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Pulled out of hole and laid down BHA. Ran in hole with 4.5" liner Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 92500.00 33 1-May-2015 12:00 AM Current Pump & Flow Data: Max 1-1-CT-G-X-I-NO-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2L-316 ConocoPhillips TARN 2L-Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Condition 1,2,CT,S,X,1,CT,TD Bit # 2 8.0 9.875 9.85 PDC 9.90 Size 3 12187' 2518' 100% Gas In Air=10,000 UnitsN/AConnection 159 Tools API FL Chromatograph (ppm) 2528' 12197' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min 45Background (max) Trip Average 73 Mud Type Lst Type PDC Kla-Shield 4.1 12197' 14990'21 14990' Depth in / out YP (lb/100ft2) 10.10 687941 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 9 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-902329981 RIH w/ 4.5" Liner PV 9669' 6.5 0.383 Footage 112.50 2429' 91.80 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 9 Gas Summary 0 316 157 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 14990' 14990' 0' Max @ ft Current Date: Time: 23 in 1 N/AMinimum Depth C-5n N/A C-2 73 SPP (psi) Gallons/stroke TFABit Type Depth 1.348 MBT pH 0 63 0 Siltst 7.625" Units* Casing Summary Lithology (%) 1469 25 907-659-7599Unit Phone: 247 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Macy Willams Set AtSize 45.5 Grade 10.75" (max)(current) Intermediate 46 0 Cly 239 Bottoms Up Time 673 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes WELL INFORMATION Created On : May 12 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2L-316 (Enterprise) Job Number :AK-XX-0902329981 Rig Name :Doyon 25 Field Name :Kuparuk River Unit County :North Slope Borough Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2566.91 33.06 89.00 2,426.83 12.57 N 720.13 E 12.57 1.29 2660.98 35.30 85.77 2,504.65 15.02 N 772.90 E 15.02 3.06 2755.55 37.69 84.46 2,580.67 19.83 N 828.94 E 19.83 2.66 2850.56 40.24 85.17 2,654.54 25.22 N 888.43 E 25.22 2.72 2945.42 44.44 89.91 2,724.66 27.85 N 952.22 E 27.85 5.56 3040.52 49.36 91.65 2,789.62 26.87 N 1,021.62 E 26.87 5.34 3134.59 53.44 93.62 2,848.30 23.45 N 1,095.04 E 23.45 4.64 3229.81 56.32 95.67 2,903.08 17.12 N 1,172.65 E 17.12 3.50 3324.34 58.61 95.56 2,953.91 9.32 N 1,251.96 E 9.32 2.42 3418.58 59.09 95.62 3,002.66 1.47 N 1,332.23 E 1.47 0.51 3513.61 59.56 97.61 3,051.15 7.95 S 1,413.41 E -7.95 1.87 3608.38 60.39 98.96 3,098.57 19.78 S 1,494.60 E -19.78 1.51 3703.06 63.19 99.75 3,143.32 33.35 S 1,576.91 E -33.35 3.05 3797.41 66.03 98.91 3,183.77 47.16 S 1,661.01 E -47.16 3.12 3891.81 68.54 98.30 3,220.22 60.18 S 1,747.11 E -60.18 2.72 3987.83 71.42 98.54 3,253.09 73.39 S 1,836.34 E -73.39 3.01 4082.12 74.12 98.80 3,281.02 86.97 S 1,925.36 E -86.97 2.88 4176.24 73.90 98.58 3,306.94 100.64 S 2,014.80 E -100.64 0.32 4271.64 73.93 99.65 3,333.38 115.16 S 2,105.31 E -115.16 1.08 4365.03 73.94 101.28 3,359.22 131.46 S 2,193.55 E -131.46 1.68 4460.49 73.91 102.66 3,385.66 150.48 S 2,283.29 E -150.48 1.39 4554.08 73.91 102.71 3,411.59 170.23 S 2,371.01 E -170.23 0.05 4648.41 73.87 102.09 3,437.77 189.69 S 2,459.53 E -189.69 0.63 4742.83 73.94 102.21 3,463.95 208.78 S 2,548.21 E -208.78 0.14 4837.94 73.94 102.07 3,490.26 228.00 S 2,637.57 E -228.00 0.14 4932.46 73.85 102.31 3,516.48 247.18 S 2,726.33 E -247.18 0.26 5026.70 73.82 100.36 3,542.72 264.97 S 2,815.07 E -264.97 1.99 5216.11 73.82 96.70 3,595.51 291.94 S 2,994.93 E -291.94 1.86 5310.55 73.85 96.63 3,621.81 302.47 S 3,085.03 E -302.47 0.08 5405.55 73.94 97.21 3,648.16 313.47 S 3,175.63 E -313.47 0.59 INSITE V8.1.10 Page 1Job No:AK-XX-0902329981 Well Name:2L-316 (Enterprise)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 5500.48 73.91 98.34 3,674.44 325.81 S 3,266.01 E -325.81 1.14 5595.51 74.00 99.30 3,700.71 339.81 S 3,356.26 E -339.81 0.98 5690.08 74.00 101.37 3,726.78 356.12 S 3,445.68 E -356.12 2.10 5784.05 74.47 103.49 3,752.31 375.58 S 3,533.99 E -375.58 2.23 5879.61 74.74 105.12 3,777.68 398.35 S 3,623.26 E -398.35 1.67 5969.07 74.30 105.77 3,801.56 421.31 S 3,706.36 E -421.31 0.86 6068.42 74.00 105.79 3,828.70 447.30 S 3,798.33 E -447.30 0.30 6162.52 72.96 107.16 3,855.45 472.88 S 3,884.84 E -472.88 1.78 6256.49 73.13 107.19 3,882.86 499.42 S 3,970.72 E -499.42 0.18 6352.40 73.10 107.63 3,910.71 526.88 S 4,058.29 E -526.88 0.44 6447.45 73.05 108.43 3,938.39 555.03 S 4,144.76 E -555.03 0.81 6541.66 73.01 107.79 3,965.88 583.04 S 4,230.40 E -583.04 0.65 6636.18 73.17 107.74 3,993.38 610.63 S 4,316.52 E -610.63 0.18 6730.84 74.60 106.27 4,019.65 637.22 S 4,403.48 E -637.22 2.12 6825.55 74.54 106.81 4,044.85 663.21 S 4,491.00 E -663.21 0.55 6920.11 74.62 106.47 4,069.99 689.31 S 4,578.34 E -689.31 0.36 7015.32 74.65 107.45 4,095.22 716.09 S 4,666.15 E -716.09 0.99 7110.53 74.59 107.73 4,120.47 743.83 S 4,753.66 E -743.83 0.29 7205.57 74.22 107.13 4,146.02 771.25 S 4,841.00 E -771.25 0.72 7300.00 74.00 106.56 4,171.88 797.57 S 4,927.92 E -797.57 0.63 7395.01 74.08 105.78 4,198.00 823.01 S 5,015.66 E -823.01 0.79 7489.62 74.06 104.87 4,223.97 847.06 S 5,103.40 E -847.06 0.93 7583.63 74.06 104.02 4,249.79 869.61 S 5,190.93 E -869.61 0.87 7678.34 74.09 103.77 4,275.78 891.48 S 5,279.34 E -891.48 0.26 7772.93 74.09 105.20 4,301.71 914.23 S 5,367.42 E -914.23 1.45 7867.45 74.11 106.36 4,327.60 938.95 S 5,454.89 E -938.95 1.18 7962.19 74.09 108.80 4,353.56 966.47 S 5,541.74 E -966.47 2.48 8056.39 74.18 109.75 4,379.31 996.38 S 5,627.28 E -996.38 0.97 8150.73 73.61 109.66 4,405.48 1,026.94 S 5,712.61 E -1026.94 0.61 8244.95 73.70 109.48 4,432.00 1,057.22 S 5,797.80 E -1057.22 0.21 8340.09 73.58 109.08 4,458.80 1,087.36 S 5,883.96 E -1087.36 0.42 8434.93 73.60 109.51 4,485.59 1,117.43 S 5,969.83 E -1117.43 0.44 8529.42 73.64 108.57 4,512.24 1,147.00 S 6,055.52 E -1147.00 0.96 8623.95 73.61 108.79 4,538.89 1,176.05 S 6,141.44 E -1176.05 0.23 8718.56 74.14 109.14 4,565.16 1,205.59 S 6,227.39 E -1205.59 0.66 8813.60 74.17 109.14 4,591.11 1,235.56 S 6,313.77 E -1235.56 0.03 8908.18 74.08 107.80 4,616.98 1,264.38 S 6,400.05 E -1264.38 1.37 9003.06 74.20 107.12 4,642.91 1,291.77 S 6,487.12 E -1291.77 0.70 9097.82 74.12 106.02 4,668.78 1,317.77 S 6,574.49 E -1317.77 1.12 9192.11 74.14 106.87 4,694.56 1,343.44 S 6,661.48 E -1343.44 0.87 9287.37 74.03 107.18 4,720.69 1,370.26 S 6,749.07 E -1370.26 0.33 9381.66 74.17 107.00 4,746.52 1,396.91 S 6,835.75 E -1396.91 0.24 9476.49 74.14 107.01 4,772.41 1,423.59 S 6,922.99 E -1423.59 0.03 9571.44 74.14 108.49 4,798.36 1,451.44 S 7,009.97 E -1451.44 1.50 9666.22 74.08 108.13 4,824.31 1,480.07 S 7,096.51 E -1480.07 0.37 INSITE V8.1.10 Page 2Job No:AK-XX-0902329981 Well Name:2L-316 (Enterprise)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 9760.66 74.08 108.53 4,850.21 1,508.63 S 7,182.72 E -1508.63 0.41 9855.63 74.15 107.53 4,876.21 1,536.91 S 7,269.58 E -1536.91 1.02 9949.63 74.02 108.62 4,901.99 1,564.95 S 7,355.51 E -1564.95 1.12 10044.46 74.05 107.91 4,928.07 1,593.53 S 7,442.09 E -1593.53 0.72 10139.34 74.47 106.88 4,953.81 1,620.83 S 7,529.24 E -1620.83 1.13 10233.24 75.06 106.23 4,978.48 1,646.64 S 7,616.08 E -1646.64 0.92 10327.81 75.54 107.26 5,002.48 1,673.00 S 7,703.68 E -1673.00 1.17 10422.74 77.50 106.82 5,024.61 1,700.05 S 7,791.93 E -1700.05 2.11 10516.49 80.09 106.30 5,042.83 1,726.25 S 7,880.07 E -1726.25 2.82 10611.75 80.49 105.50 5,058.89 1,751.97 S 7,970.38 E -1751.97 0.93 10706.46 80.66 105.18 5,074.40 1,776.69 S 8,060.48 E -1776.69 0.38 10801.55 80.06 105.15 5,090.33 1,801.22 S 8,150.96 E -1801.22 0.63 10896.53 80.05 106.12 5,106.73 1,826.43 S 8,241.05 E -1826.43 1.01 10990.82 79.03 106.69 5,123.85 1,852.61 S 8,330.00 E -1852.61 1.23 11084.14 79.05 106.83 5,141.59 1,879.03 S 8,417.72 E -1879.03 0.15 11179.03 79.05 107.34 5,159.61 1,906.40 S 8,506.78 E -1906.40 0.53 11274.58 79.13 108.30 5,177.70 1,935.12 S 8,596.10 E -1935.12 0.99 11369.07 79.10 108.53 5,195.54 1,964.43 S 8,684.13 E -1964.43 0.24 11463.44 79.10 108.73 5,213.39 1,994.03 S 8,771.95 E -1994.03 0.21 11557.78 79.19 107.89 5,231.15 2,023.14 S 8,859.91 E -2023.14 0.88 11652.59 79.64 108.27 5,248.57 2,052.06 S 8,948.50 E -2052.06 0.62 11748.14 79.57 108.57 5,265.81 2,081.76 S 9,037.67 E -2081.76 0.32 11842.29 79.51 108.56 5,282.90 2,111.24 S 9,125.43 E -2111.24 0.06 11936.81 79.57 110.83 5,300.07 2,142.56 S 9,212.94 E -2142.56 2.36 12031.50 79.74 112.88 5,317.07 2,177.23 S 9,299.39 E -2177.23 2.14 12126.71 79.98 115.60 5,333.84 2,215.71 S 9,384.84 E -2215.71 2.82 12220.64 80.17 119.87 5,350.03 2,258.76 S 9,466.72 E -2258.76 4.48 12270.43 81.21 122.80 5,358.09 2,284.31 S 9,508.68 E -2284.31 6.17 12315.32 81.83 125.84 5,364.71 2,309.34 S 9,545.34 E -2309.34 6.84 12368.00 81.77 129.58 5,372.23 2,341.23 S 9,586.58 E -2341.23 7.03 12410.45 81.84 132.89 5,378.28 2,368.92 S 9,618.18 E -2368.92 7.72 12462.71 81.76 136.65 5,385.74 2,405.34 S 9,654.89 E -2405.34 7.12 12505.42 81.77 138.41 5,391.85 2,436.52 S 9,683.43 E -2436.52 4.08 12561.12 81.90 139.68 5,399.77 2,478.16 S 9,719.57 E -2478.16 2.27 12600.04 82.22 140.94 5,405.14 2,507.82 S 9,744.19 E -2507.82 3.31 12695.01 83.60 144.28 5,416.87 2,582.69 S 9,801.40 E -2582.69 3.78 12789.71 84.39 148.16 5,426.78 2,660.95 S 9,853.75 E -2660.95 4.16 12884.18 84.70 151.23 5,435.76 2,742.13 S 9,901.20 E -2742.13 3.25 12979.32 86.08 154.91 5,443.41 2,826.67 S 9,944.14 E -2826.67 4.12 13075.10 87.59 158.48 5,448.70 2,914.48 S 9,981.97 E -2914.48 4.04 13170.26 85.15 158.91 5,454.72 3,002.95 S 10,016.47 E -3002.95 2.60 13265.22 84.57 160.48 5,463.23 3,091.65 S 10,049.29 E -3091.65 1.76 13359.96 85.01 161.98 5,471.84 3,180.98 S 10,079.65 E -3180.98 1.64 13454.46 86.46 164.82 5,478.86 3,271.28 S 10,106.56 E -3271.28 3.37 13549.07 86.84 164.11 5,484.39 3,362.28 S 10,131.86 E -3362.28 0.85 INSITE V8.1.10 Page 3Job No:AK-XX-0902329981 Well Name:2L-316 (Enterprise)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13644.37 88.21 162.74 5,488.51 3,453.53 S 10,159.02 E -3453.53 2.03 13739.33 88.69 160.47 5,491.08 3,543.59 S 10,188.97 E -3543.59 2.44 13833.72 88.59 153.12 5,493.32 3,630.26 S 10,226.13 E -3630.26 7.79 13928.88 89.57 157.48 5,494.85 3,716.69 S 10,265.88 E -3716.69 4.70 14023.98 91.04 152.29 5,494.34 3,802.76 S 10,306.22 E -3802.76 5.67 14118.00 90.87 153.17 5,492.78 3,886.32 S 10,349.30 E -3886.32 0.95 14212.79 90.60 156.68 5,491.56 3,972.16 S 10,389.46 E -3972.16 3.71 14307.10 90.49 156.83 5,490.66 4,058.81 S 10,426.68 E -4058.81 0.20 14402.56 89.53 157.25 5,490.65 4,146.70 S 10,463.92 E -4146.70 1.10 14497.09 89.60 160.63 5,491.36 4,234.90 S 10,497.88 E -4234.90 3.58 14592.25 89.05 162.61 5,492.49 4,325.20 S 10,527.88 E -4325.20 2.16 14686.70 89.19 162.06 5,493.94 4,415.18 S 10,556.54 E -4415.18 0.60 14781.82 89.43 160.62 5,495.08 4,505.29 S 10,586.97 E -4505.29 1.53 14876.92 89.16 157.28 5,496.25 4,594.03 S 10,621.12 E -4594.03 3.52 14930.00 88.54 156.30 5,497.32 4,642.80 S 10,642.03 E -4642.80 2.18 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 18.65 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 14,930.00 feet is 11,610.71 feet along 113.57 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 4Job No:AK-XX-0902329981 Well Name:2L-316 (Enterprise)Survey Report
