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215-073
• • pTD .25--a73 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent Thursday, November 16, 2017 2:13 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: CD5-05 (PTD 215-073) Flowing Water in Conductor Report Follow Up Flag: Follow up Flag Status: Flagged Victoria, CRU producer CD5-05(PTD 215-073) has recently been noted as having water flowing to surface through the surface casing by conductor annulus. CPAI suspects this water to be from the same shallow source water that was encountered on CD5-313 (PTD 215-084),as well as other CD5 wells. We will take initial samples for analysis and collect water at the wellhead to monitor the flow volume. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED 1 Nov ConocoPhillipsRECE Alaska NOV 10 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 30, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 SUNNED MAP 1201?, Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU).Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped October 29th 2016. The corrosion inhibitor/sealant was pumped on October 30th 2016. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call Aaron Applehans or Roger Winter at 907-659-7506,if you have any questions. Sincerely, / Aaron Applehans ConocoPhillips Well Integrity Field Supervisor , e r ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 10/30/2016 CD5 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD5-01 50103207360000 2160220 1.33' .17 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-02 50103207370100 2160680 1' _ .1 bbl .66' 10/29/2016 5 gal 10/30/2016 CD5-03 50103207180000 2151460 _ 1.08' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 CD5-04 50103207110000 2150720 .875' .07 bbl .66' 10/29/2016 5.1 gal 10/30/2016 r' CD5-05 50103207120000 2150730 2.25' NA 2.25' 5/29/2016 18 gal 10/30/2016 CD5-07 50103207340000 2160040 1.42' .2 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-08 50103207410000 2160510 4.75' .71 bbl 1.83 10/29/2016 CD5-12 50103207420000 2160520 2.58' .47 bbl 0.66 10/29/2016 5 gal 10/30/2016 CD5-315 50103207160000 2151370 1' .1 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-21 50103207380000 2160310 .75' .6bbl 0.66 10/29/2016 3.4 gal 10/30/2016 1 STATE OF ALASKA AL OIL AND GAS CONSERVATION COMM SION 2 6 9 4 6 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon - Plug Perforations P Fracture Stimulate Iv Pull Tubing I Operations Shutdown I Performed: Suspend rPerforate P Other Stimulate I Alter Casing 1 Change Approved Program I Plug for Redrill P Perforate New Pool F Repair Well Re-enter Susp Well P 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Iv Exploratory 215-073 3.Address: 6.API Number: Stratigraphic P Service P P. O. Box 100360,Anchorage,Alaska 99510 50-103-20712-00 7.Property Designation(Lease Number): 8.Well Name and Number: ASRC NPR4,ASRC NPR2,ADL 387208 CRU CD5-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 17900 feet Plugs(measured) None true vertical 7529 feet Junk(measured) None Effective Depth measured 17888 feet Packer(measured) 10537, 10997 true vertical 7529 feet (true vertical) 7367, 7462 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 116 116 SURFACE 2232 10 3/4 2267 2150 INTERMEDIATE 11142 7 5/8 11177 7480 LINER 6891 41/2 17888 7529 N NE® APR ® 8 Ha Perforation depth: Measured depth: 11721-17129 �� RECEIVED True Vertical Depth: 7487-7531 MAR 0 2 2016 Tubing(size,grade,MD,and TVD) 3.5, L-80, 11013 MD, 7465 TVD AOGCC Packers&SSSV(type, MD,and TVD) PACKER-BAKER PREMIER PACKER @ 10537 MD and 7367 TVD PACKER-Baker HRD-3 ZXP Linder Top Packer @ 10997 MD, 7463 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11721-17129 Treatment descriptions including volumes used and final pressure: Total well - 10 stages 741k lbs placed.....See attached schematic for full FRAC details., 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1722 - 3 263 962 Subsequent to operation 4106 - 154 1544 560 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory Development i Service I- Stratigraphic Copies of Logs and Surveys Run . . 16.Well Status after work: V 1 Y J Oil 1� Gas WDSPL � Printed and Electronic Fracture Stimulation Data 7 GSTOR I WINJ 1..... WAG , GINJ i SUSP I 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: 316-001 Contact Robert Blakney @.265-6417 Email Robert.G.Blakney@conocophillips.com Printed Name Robert Blakney Title Completions Engineer Signature Phone:265-6417 Date / Z/ 6 krL 3/1irY1,6ED9.e-u Form 10-404 Revised 5/Z015, �`'w r RBDMS LI- MAR 0 4 2016 Submit Original Only 3/ 7' /// /2ofG CD5-05 DTTMS JOBTYP SUMMARYOPS 1/23 FRACTURING DRIFT & BRUSH DS NIP @ 10569' RKB, STALL OUT © 10990' SLM. SET 2.81" CSA-2 PLUG @ 10569' RKB. SET BAITED JD ON PLUG © 10544' SLM. PULLED 1" GLV's @ 7604' &4197' RKB. SET 1" DV'S @ SAME. PULLED 1" OV @ 10417' RKB. READY FOR CIRC-OUT. IN PROGRESS 1/24 FRACTURING CIRC-OUT W/ 365 BBLS SW BRINE, 85 BBLS DIESEL. U-TUBE FREEZE PROTECT. SET 1" DV @ 10417' RKB. ATTEMPT MIT-T FAILED. PERFORMED MIT-IA****PASS****. IN PROGRESS 1/24 FRACTURING CIRC-OUT, PUMPED 365 BBLS OF 60* CORROSION INHIBITED BRINE DOWN TBG FOLLOWED BY 86 BBLS OF 45* DIESEL RETURNS UP IA, ALLOWED TBG AND IA TO U- TUBE FOR FREEZE PROTECT. InR (nMPI FTF 1/25 FRACTURING PULLED 2.81" CSA-2 PLUG @ 10569' RKB. DRIFT TO 25' SLM W/3.85" G-RING. READY FOR FRAC 1/30 FRACTURING Rig up for frac and attempt to pressure test. Starting pressure testing © 2 pm, chased small drips until 7pm. Passing pt @ 7pm. Too late to start frac'ing. post-poned job until tomorrow. 1/31 FRACTURING started down hole @ 12:11 started mini frac© 12:30- ISIP -4730 psi (BHG) -.635 psi/ft, no closure seen after 20 mins. Fluid efficency is > 34% or higher average values: stage 1 -25 bpm @ 5805 psi 57/72k lbs placed stage 2 -25 bpm © 5930 psi 72/73k lbs placed stage 3 -27 bpm ©6083 psi 72/72k lbs placed stage 4 -27 bpm © 6428 psi 72/72k lbs placed stage 5 -28 bpm © 6314 psi 74/72k lbs placed ISIP-4923 psi @4:53 pm total - 348,100 lbs placed, 97% of design 2/2 FRACTURING Completed stages 6-10 392k lbs 87% of design placed average values stage 6 - 32/90 k @ 28 bpm -went to flush after issues with the sand belt stage 7 - 91/90 k @ 28 bpm stage 8 - 89/90 k @ 28 bpm stage 9 -90/90 k @ 27 bpm stage 10 -92/90 k @ 27 bpm isip-4875 psi @ BHG total well - 10 stages 741/800 k lbs placed 2/11 FRACTURING JOB POSTPONED DUE TO WEATHER. 2/19 FRACTURING RAN 2.5" X 5' DD BAILER TO 10600' SLM. RAN FB-BLB & 2.80" G.RING TO 10560' SLM. SET 2.81" CAT-SV @ 10570' RKB. PULLED 1" DV'S @ 10417', 7605', AND 4197' RKB. SET 1" OV© 10417' RKB. SET 3/16" " GLV' (TRO = 1906) © 7605'. BRUSH GLM @ 4197' RKB. SET 3/16" GLV (TRO = 1985) @ 4197' RKB. ATTEMPT TO MITT. IA TRACKING. RAN HOLE FINDER w/COLLAR STOP BTM. TEST TBG © 10442' & 10388' SLM ISOLATING GLM @ 10417' RKB. PASSED TEST ABOVE GLM. PERFORM MITT TO 2500 PSI. **PASS**. PULLED CAT SV © 10570' RKB. READY FOR FLOW BACK. • 0 C N O oO c o O N c cO M j O co 2 II F 02 _co (O P Ea) V EWON O N 4) a7 N O U 0 Z < Z a)Ta U) U) CO c CO m .0 N O LO O CO CD CD CW O (D N O O to aJ CS) CO O O O (^7 CD CO N U) CO N- N ,- N N C •- T C Q E C O e x N me ow ow , c cc oma° , ow ow op r 0 f0 v*- o r o 0 DC m r °J m (N m 0 E .O •.' 'O 0 o (N ,� .0 0) o CO U) 0 V) Ur) © 0 0 0 o 0 o o o o C LL 0 0 0 0 0 0 o o o o O I U CD o, oa , 4, 0,0 0 0 0 0 0 0 0 0 0 0 0 > O 0 0 0 0 0 0 0 O rl 0 0 r1 0 r+ 0 in o 0 0 0 0 0 .-�CD .119 0 0 0 0 m Cl lO O Q ti c N Cc (5 C O a a> a 6. 'Tc C o 2 c O 0 To ' a) U u v v L N N V r r N •E a # 9 CO Q.) a) N •O cCD c co 0 0 L L -0 a) CO a) '9 W a) O co CO a) Lo 0 Q 3 m (n .c r W L- O o o '- N- Q < Q 0 c c _O Z Z Z Z Z rn U)) 0 N. 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U 7 N O o C O C E U (A _c L csj T'x - O ' (O a) -O 3 p L a O _ N Via. N dO_ m U .L-. E. N •-• _ O O cC c E o 0 C U N N 0 Ca .LC 1- O q L O N 7 N OO C C O O N ❑ C f) N U > ' -aCa w L L O .� C O)w I] LL C O O @ 0 p (n L (q E oo_ c o .(n TT) o o ° o j O C L U N U ❑ N a)~ : Z Q a'a 2 WNS PROD 1110 CD5-05 r' C)t1 � 0C f flii ps 2 14 Well Attributes Max Angle&MD TD a Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Ilnel(°) MD(ftKB) Act Btm(ftK[.) , _,, " 501032071200 ALPINE PROD 90.56 12,173.13 17,900.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD5.05,3/2201610:02:08 AM SSSV:NIPPLE Last WO: 36.50 9/8/2015 Vertical schematic(actuel). Annotation Depth(ftKB) End Dale Annotation Last Mod By End Date HANGEI;adze-E> -.I- i Last Tag: Rev Reason:FRACTURE UPDATE lehallf 3/2/2016 f Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 20 19.000 36.5 115.5 115.5 78.60 B � _� , Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 35.2 2,267.0 2,150.5 45.50 L-80 Hyd 563 CONDUCTOR;36.5-115.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread I. INTERMEDIATE 75/8 6.875 35.2 11,176.8 7,480.3 29.70 LH BTCM ill Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ill LINER 4 1/2 3.958 10,997.3 17,888.0 7,529.4 12.60 L-80 IBT-M NIPPLE;537.3 _ Liner Details it Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 10,997.3 7,462.9 82.80 PACKER BAKER HRD-3 ZXP LINER TOP PACKER 5.270 11,018.6 7,465.5 83.23 NIPPLE BAKER RS NIPPLE 4.050 11,020.9 7,465.8 83.28 HANGER BAKER DG FLEXLOCK LINER HANGER 4.170 11,030.8 7,466.9 83.48 XO Reducing Cross over,5"BTC-M x 4-1/2"IBT-M,L-80 3.880 11,651.6 7,487.3 90.12 SLEEVE CAMCO SLIDING SLEEVE W/D PROFILE(OPEN 2.750 SURFACE:35.2-2,267.0 • DOWN) GAS LIFT;4,196.8 11,721.4 7,487.3 89.99 FRAC PORT FRAC PORT#9,BALL 2.063"(2.05"ID) 2.050 INS 12,351.4 7,486.0 89.84 FRAC PORT FRAC PORT#8,BALL 2.000"(1.9541D) 1.954 f ) 13,018.1 7,493.5 89.35 FRAC PORT FRAC PORT#7,BALL 1.938")1.890"(D) 1.890- 13,691.4 7,503.0 89.85 FRAC PORT FRAC PORT#6,BALL 1.875"(1.83"ID) 1.830 GAS LIFT;7,604.8 It 14,359.3 7,504.9 89.77 FRAC PORT FRAC PORT#5,BALL 1.813"(1.77(D) 1.770 111 15,027.4 7,512.1 88.71 FRAC PORT FRAC PORT#4,BALL 1.75"(1.71"ID) 1.710 it 15,739.5 7,517.3 89.52 FRAC PORT FRAC PORT#3,BALL 1.688"(1.64"ID) 1.640 GAS LIFT;10,417.4 If. 16,410.8 7,521.2 89.65 FRAC PORT FRAC PORT#2,BALL 1.625"(1.591D) 1.590 it 17,126.4 7,531.4 89.98 FRAC PORT FRAC PORT#1,BALL 1.563"(1.551D) 1.550 - le Tubing Strings GAUGE;10,476.4 �- Tubing Description Strang Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection at TUBING-41/2"x3 31/2 2.992 30.8 11,012.6 7,464.8 9.30 L-80 EUE 1/2"@120.6 Completion Details II Nominal ID PACKER;10,537.2 - Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) I III 30.8 30.8 0.03 I HANGER FMC ALP HORIZTONAL HANGER(METAL TO METAL 3.958 IN SEALS) NIPPLE;10,569.8 '^_' 120.6 120.6 0.11 I XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 al 2.91" ilf 537.3 537.2 2.80 NIPPLE CAMCO DS LANDING NIPPLE 2.875 LOCATOR;10,9952 10,476.4 7,345.4 68.01 GAUGE CAMCO SLB SOLID GAUGE MANDREL 2.920 WLEG;10,996.2 10,537.2 7,367.2 70.15'PACKER BAKER PREMIER PACKER 2.880 lx,--,-.. 10,569.8 7,377.9 71.58'NIPPLE CAMCO DS LANDING NIPPLE(PLUG PULLED 10 2 15) 2.812 4 10,995.2 7,462.7 82.76 LOCATOR BOT FLUTED NO GO LOCATOR 3.000 10,996.2 7,462.8 82.781 WLEG BAKER WLEG 2.970 Perforations&Slots I i I Shot IDens Top(TVD) Btm(TVD) (shotslf INTERMEDIATE:35.1-11,176.8 A. Top(ftKB) BM(ftKB) _ (ftKB) (ftKB) Zone Date t) Type Com 11,721.4 11,724.1 7,487.3• 7,487.3 9/5/2015 PERFP Frac Port 1 r 12,351.4 12,354.1 7,486.0• 7,486.0 9/5/2015 PERFP Frac Port - 13,018.1 13,020.9 7,493.5 I 7,493.5 9/5/2015 PERFP Frac Port 13,691.4 13,694.1 7,503.0• 7,503.0 9/5/2015 PERFP Frac Port PERFP;11,721.4-11,724.1 14,359.3 14,362.1 7,504.9 7,504.9 9/5/2015 PERFP Frac Port 15,027.4 15,030.1 7,512.1 7,512.1 9/5/2015 PERFP Frac Port PERFP;12,351.4-12,354.1 Tr 15,739.5 15,742.2 7,517.3' 7,517.3 9/5/2015 PERFP Frac Port 16,410.8 16,413.5 7,521.2' 7,521.2 9/5/2015 PERFP Frac Port 17,126.4 17,129.2 7,531.4 i 7,531.4 9/5/2015 PERFP Frac Port PERFP;13,018.1-13,020.9 ^J.l' Stimulations&Treatments _ Sand Frac;11,721.0 Min Top Max Btm Depth Depth Top(TVD) Blm(TVD) PERFP;13,891.4-13,894.1 11 f r (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 15,027.0 17,126.0 7,512.1 7,531.4 Sand Frac 1/31/2016 Pumped Stages 1-5 348100 lbs of 1620 carbolyte placed ISIP 4923 PSI-BHG 11,721.0 I 14,362.0 7,487.3 7,504.9 Sand Frac ..12/2/2016 Pumped Stages 6-10 392000 lbs of 1620 carbolyte PERFP;14,359.3-14,362.1 'kik placed Total Well 741000 lbs of 1620 carbolyte placed.ISIP 4875 PSI-BHG Mandrel Inserts St I ati PERFP;15,027.4-15,030.1 on N ToTop(ND) Valve Latch Part Size TRO Run Make Model OD(in) Sera _ p(ftKB) (ftKB) Type Type (in) (psi) Run Date Com 1 4,196.8 3,432.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,985.0 2/20/2016 2 7,604.6 5,613.6 CAMCO KBMG 1 GAS LIFT GLV BK - 0.188 1,906.0 2/20/2016 PERFP;15,739.5-15,7422 1l 1 3 10,417.4 7,322.5 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/20/2016 Sam Frac:15,027.0 Notes:General&Safety End Date Annotation PERFP;18,410.8-18,413.5 0l I 10/1/2015 NOTE: BALL/ROD AT 10,570'PULLED 10/1/2015 2/2/2016 NOTE: Pumped 10 stage frac-741K lbs total PERFP;17,126.4-17,129.1 Nil' LINER;10,997.3-17,888.0 x• PTD 7/5——.03 • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, September 02, 2015 10:47 AM To: 'Earhart, Will C' Cc: Bettis, Patricia K (DOA) Subject: RE: CRU CD5-05 (PTD 215-073)- MWD Failure- Request to Drill Ahead Will, Approval is granted to drill ahead up to 700'without MWD data as described below. Thanx, Victoria 5(00 D MAR 0 8 2016 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.loepp@alaska.gov From: Earhart, Will C [mailto:William.C.Earhart@conocophillips.com] Sent: Wednesday, September 02, 2015 10:41 AM To: Loepp, Victoria T(DOA) Cc: Stinson, Rob D Subject: CRU CD5-05 (PTD 215-073)- MWD Failure- Request to Drill Ahead Victoria, Per your verbal approval,we will drill ahead<700ft measured depth without MWD data on CRU CD5-05 (215-073). Due to a MWD tool failure,communication from downhole tools ceased at 17,571' MD within the Alpine A reservoir. The intermediate casing shoe is set at 11,175' MD.At the time of the failure '6400ft of horizontal section had been drilled. Given that we saw little to no build or walk tendencies from the BHA,we are confident in our ability to very predictably drill forward towards planned TD. We are currently 5ft from the interpreted top of the Alpine A reservoir so given the predictability of the BHA to this point we are comfortable that we will stay within zone. In the rare chance we exit the Alpine A,given the competency of the Alpine B formation above us we see little to no incremental risk in this excursion. 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'U U wO c £ D. 7 O •a 0m o o0d w W W W W W W W W W W W W W J 3 Z 0 a 0 • i o I 9 0 o 1N 9 N 0 n O Z ct N ✓ Q) U g o T on N o O 1 6 z 3 E Q J Z O 7 Qj N m e6 11 Q (f) 0 C/ N O N d U CL J 1 J N W a I 1.� 0 v U J O V 0 O 11 Q w N I GI 3 o 1 aii CD ON a V CO U I rn ca W 0 I- ~ in Z I O N W > W J a) d CO ICC o " 0 H i I< z E Go E U R z I a) `� rn O 1.0 (NICO r lill 0 CO m o in o 1 Gf N N d W mre o 0 0 w c • d O) ! C O O !, I 11 V p O O «0. c U cc E .c E 11) H E 0 E d E a 2 c0.> U CL Cl 0 •OF 7•�, • ).'%'\ 1//7; SA THE STATE Alaska Oil and Gas �... � ,� of/A T /& sKAL Conservation Commission 7 == - 1ZL1-1 _ �_ 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \ '4 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Robert Blakney Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-05 Permit to Drill Number: 215-073 Sundry Number: 316-001 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this /5 day of January, 2016. RBDMS JAN 1 9 2016 • • RECEIVED STATE OF ALASKA JAN 0 42016 ALASKA OIL AND GAS CONSERVATION COMMISSION p75 i$7 d /6 APPLICATION FOR SUNDRY APPROVALS AOC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑✓ • Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc., Exploratory ❑ Development El. 215-073 • 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20712-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? IVFl CRU CD5-05 . Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number): 10. Field/Pool(s): ASRC NPR4, ASRC NPR2, ADL387208 . Colville River Unit/Alpine Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth'MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 91(13 17,900' 7,529' 1}ggk 7-niI 7,000 Casing Length Size MD TVD Burst Collapse Structural Conductor 115.5' 20" 115.5' 115.5' Surface 2,232' 10-3/4" 2,267' 2,150' Intermediate 11,141' 7-5/8" 11,176' 7,480' Production Liner 6,891' 4-1/2" 17,888' 7,529' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic , See Attached Schematic 3-1/2" L-80 11,012' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM INSTALLATION no SSSV , 10,537'MD/7,367'TVD, no SSSV 12.Attachments: Proposal Summary E Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 1st,2016 OIL ❑., • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Robert Blakney @ 907-265-6417 Email Robert.G.Blakney@conocophillips.com Printed Name Robert Blakney Title Completions Engineer 211 y\32A- � ` Uk \o‘xxviii lIt-1I?Ovw Signature Phone 907-265-6417 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3/• • iD/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No n" Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 10 - 404 APPROVED BY Approved by: 0 M ONER THE COMMISSION Date: /� /S...-/ , p \I P � irov Subs int upli and Form 10-403 R ised 11/2015 A t t v li 2 months from the to of a proval. chmen s in uplicate V`T_ 1// //6 I-?Pn"AS L. JAN 1 9421 /g/i6 �rits 4111 it A WNS PROD CD5-05 ConocoPhillips Well Attributes } A Max Angle&MD TD ?ln;,,,a Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) �g t.';7 501032071200 ALPINE PROD 90.56 12,173.13 17,900.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD5-05.10/5/20153.12:50 PM SSSV:NIPPLE Last WO: 36.50 9/8/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,30.8-(m. ■ "' Last Tag: Rev Reason:PULLED RHC PLUG,GLV 0/0 lehallf 10/5/2015 LEK asing rings li ., Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 5 y■ CONDUCTOR 20 19.000 36.5 115.5 1155 7860 B �� _ :ISM Cas ng Der phon 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Tap Thread [[ SURFACEsc10 3/4 9.950 35.2 2,267.0 2,150.5 45.50 L-80 Hyd 563 CONDUCTOR E, 36 5-115 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...Wt/Len II...Grade Top Thread �� INTERMEDIATE 75/8 6.875 35.2 11,176.8 7,480.3 29.70 L80 BTCM `kms:; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 10,997.3 17,888.0 7,529.4 12.60 L-80 IBT-M Liner Details NIPPLE 537.3 Nominal ID 1 Top(ftKB) Top(TVD)(ftKB) Top Incl l^) Item Des Com lin) 10,997.3 7,462.9 82.80 PACKER BAKER HRD-3 ZXP LINER TOP PACKER 5.270 11,018.6 7,465.5 83,23 NIPPLE BAKER RS NIPPLE 4.050 11,020.9 7.465.8 83.28 HANGER BAKER DG FLEXLOCK LINER HANGER 4.170 ' 11,030.8 7,466,9 83.48 X0 Reducing Cross over,5"BTC-M x 4-1/2"IBT-M,L-80 3.880 11,651.6 7,487.3 90.12 SLEEVE CAMCO SLIDING SLEEVE W/D PROFILE(OPEN 2.750 SURFACE,35.2-22670 ry P DOWN) I'. ; 11,721.4 7,487.3 89.99 FRAC PORT FRAC PORT#9,BALL 2.063"(2.05"ID) 3.900 GAS LFT,4,1968 r 12,351.4 7,486.0 89.84 FRAC PORT FRAC PORT#8,BALL 2.000"(1 954"ID) 3.900 12018.1 7,493.5 89.35 FRAC PORT FRAC PORT#7,BALL 1.938"(1.890"ID) 3.900 ;. 1 13.6914 7,503.0 89.85 FRAC PORT FRAC PORT#6,BALL 1 875"(1.83"I0) 3.900 14,359.3 7504.9 89,77 FRAC PORT FRAC PORT#5,BALL 1.813"(1.77"I0) 3.900 GAS LFT 7.604.6 "- 15.027.4 7,512.1 88.71 FRAC PORT FRAC PORT#4.BALL 1.75"(1.71"ID) 3.900 15,739.5 7,517.3 89.52 FRAC PORT FRAC PORT#3,BALL 1.688"(1.6410) 3.900 16,410.8 7,521.2 89.65 FRAC PORT FRAC PORT#2,BALL 1.625"(1.59"ID) 3,900 GAS LIFT.10.417.4 17,126.4 7,531 4 89.98 FRAC PORT FRAC PORT#1,BALL 1.563"(1 55"ID) 3.900 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(WD)(...Wt(lb/ft) Grade Top Connection GAUGE.14.476.4 TUBING-41/2"x3 31/2 2.992 30.8 11,012.6 7,464.8 9.30 L-80 EUE 1/2"@120.6 Completion Details Top(ftKB) Top(WD)(ftKB) Top Incl 1") Item Des Com No ina lint IID 30.8 30.8 0.03 HANGER FMC ALP HORIZTONAL HANGER(METAL TO METAL 3.958 PACKER:10,5372 = SEALS) 120.6 120.6 0.11 XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE 8r4 Pin Drifted 2.992 NIPPLE;10,569.8 __ 2.91" 537.3 537.2 2.80 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,476.4 7,345.4 68.01 GAUGE CAMCO SLB SOLID GAUGE MANDREL 2.920 LOCATOR,1,995.2 10,537.2 7367.2 70.15 PACKER BAKER PREMIER PACKER 2"880 • WLEG,10996.2 ri II ; 10,5698 7,3779 71.58 NIPPLE CAMCO DS LANDING NIPPLE(PLUG PULLED 10215) 2.812 10,995.2 7,462.7 82.76 LOCATOR BOT FLUTED NO GO LOCATOR 3.000 10,996.2+ 7,462.8 82.78 WLEG BAKER WLEG 2.970 Perforations&Slots Shot Dene l l Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,721.4 11,724.1 7,487.3 7,487.3 9/5/2015 PERFP Frac Port INTERMEDIATE:35.1-11.176.8 12,351.4 12,354.1 7,486.0 7,486.0 9/5/2015 PERFP Frac Port 1 12018.1 13,020.9 7,493.5 7,493.5 9/5/2015 PERFP Frac Port 13,691.4 13,694.1 7,503,0 7,503.0 9/5/2015 PERFP Frac Port 14,359.3 14,362.1 7,504.9 7,504.9 9/5/2015 PERFP Frac Port PERFP.11,721.4.11,774.1 15,027.4 15,030.1 7,512.1 7,512.1 9/5/2015 PERFP Frac Port 15.739.5 15,742.2 7,517.3 7,517.3 9/5/2015 PERFP Frac Port 16,410.8 16.413.5 7.521.2 7,521.2 9/5/2015 PERFP Frac Port PERFP;12,351.4-12.354.1-�.-') 17,126.4 17,129.2 7,531.4 7,531.4 9/5/2015 PERFP Frac Port Mandrel Inserts PERFP 13018.1-13,020.9 St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Com PERFP',13,681 4-13,694 1 _I 1 4,196.8 3,432.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,985.0 10/2/2015 2 7,604.6 5,613.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,906.0 10/2/2015 3 10,417.4 7,322.5 CAMCO KBMG 1 GAS LIFT OV BK - 0.250 0.0 10/2/2015 PERFP;14,359.3-14362.1 Notes:General&Safety I_1 End Date Annotation 10/1/2015 NOTE. BALL/ROD AT 10,570'PULLED 10/1/2015 PERFP,15,027.4-15.030.1 PERFP:15,739.5-15,742.2 PEREP',16.410.8-16,4135 /...-;_ PERFP,17,126.4-17,129.1 LINER 10,997.3-17 888 0 - S i 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 THE•ASKA OIL AND GAS CONSERVATION COM@if'SSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Garrett B. Haag Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-05 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Garrett B. Haag, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Garrett B. Haag. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On December 15, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 15th day of December, 2015. -ACJI Garrett B. Ha STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 15th day of December, 2015, by Garrett B. Haag. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA t;; +, NOTARY PUBLIC fr..49) REBECCA SWENSEN 7-?, My Commission Expires Aug.27,2016 • • P.O.BOX 100360 ConocoPhillips ANCHORAGE,ALASKA 99510-0360 Alaska, Inc. Garrett B.Haag,Staff Landman Land Department,ATO 1480 Phone (907)265-6297 Fax (907)263-4966 Garrett.B.Haag@cop.com December 15, 2015 VIA CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1)for CD5-05 Well AA-092347,AA-092344,ADL 387208,ADL 380075,ASRC NPRA-02,ASRC NPRA-03, ASRC NPRA-04 Colville River Unit,Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAP") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-05 Well(the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 6, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases, ASRC NPRA-04, ASRC NPRA-02, and ADL 387208 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 316 2,517 11N 4E 18 Umiat Heel 3,939 768 11N 4E 8 Umiat Bottomhole 4,797 2,749 11N 4E 16 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require ally additional information,please contact the undersigned. Sincerely, 44di Garrett B. Haag Staff Landman Attachments: Exhibits 1 &2 i • Exhibit 1 I ConocoPhillips ASRC-NPR4 CD5-05 Plat Analysis Alaska Leases 12/01/15 ASRC-NPR2 ASRC-NPR3 ADL387207 C/40 0 CDS l AA0923 7 o i 0 Aec'e 1 ASRC-NPR4 GOAlt° ADL387208 T11 NR3E T11 NR4 i ® )°: I _ I AA092344 ASRC-NPR2 Legend REFERENCES: Open Section Well Data:ConocoPhillips Alaska Well Database ATDB Surface Facilities:Nuiqsut Pad Published 06/09/15 Well Trajectory Start of Open Section N Frac Point 0 1/2 Mile Radius 0 0.15 0.3 0.45 0.6 Miles CPAI Leases • • Exhibit 2 Operator& Owner: ConocoPhillips Alaska,Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage,AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver, CO 80202 Attention: Mike Nixson,Director Land -Alaska Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa Imm,Resource Development Manager State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501-3560 Attention: Director Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut,AK 99789 Attention: Mr.Isaac Nukapigak, President • • Section 2 — Plat 20 AAC 25.283 (a)(2) ConocoPhillips CD5-05 Plat Analysis Alaska Wells 12161115 is a o v C7 Geo tax GpS Legend — Faults within Radon REFERENCES: Well Data:ConocoPhiltips Alaska Well Database ATDB — Wells in 1.12 mi Radius of Ope'Sento- Surface Facilites:Nuigsut Pad Published f81Gi),l1F Well in 1,2 mL Radius of Trajectory l�I iM Open Section I V Well Tra eaary � G G.15 0.3 3 4 C.8 CD5-DEopenBw Miles O1:2 M 4 Radius • • Wells within .5 miles Well Name API Drill Site Status Well Type CD2-33 501032038100 CD2 PA PROD CD5-04 501032071100 CD5 ACTIVE PROD CD5-03 501032071800 CD5 ACTIVE PROD CD5-313PB1 501032071470 CD5 PA N/A CD5-314 501032070700 CD5 SUSP N/A CD5-315 501032071600 CD5 ACTIVE INJ CD5-315PB1 501032071670 CD5 PA N/A • . SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10 & 3/4" casing cement pump report on 8/15/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCRETE lead cement and 15.8ppg Class G tail cement, displaced with 10.0 ppg mud. Full returns were seen throughout the job. The plug bumped @ 450 psi and the floats were checked and they held. The 7-5/8" casing cement pump report on 8/27/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Qannik Slurry cement, displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1700 psi and the floats did not hold. Pressure was held on the cement. 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 8/19/2015 the 10 & 3/4" casing was pressure tested to 3,500 psi for 30 mins. On 8/28/2105 the 7 & 5/8" casing was pressure tested to 3,500 psi for 30 mins. On 7/10/15 the 3.5" tubing was pressure tested to 3,500 psi. The 3.5" tubing will be pressure tested to 3,500 psi prior to frac'ing. The 7&5/8" casing will be pressure tested to 3,500 psi prior to frac'ing. • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 7 & 5/8" 39 L-80 9,180 psi 8,820 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi • Stimulation Surface Rig-Up �aed/Tattle Tale Tank 11 ► 1 1+ 2 1 r a m w 0 • Minimum pressure rating on all surface treating lines 10,000 psi 1`+f M11 10 • Main treating line PRV is set to 95%of max treating pressure _ • IA parallel PRV set to 3500 psi m I�o�tt • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 1.` psi. > POI►� a )lel dwnd Pop-Off Tank —DEC Pop-Off Tank — Pump Truck > 2 28'+ — zi ~ hs IJ Frac Pure t y `�'" J Fra_Puri Fra:Purip �,.I _"�.— N �." � rr Fra::.I urip Eld,f-Ur I Al :` FracPurip • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON ,f r CCINNEC7'ION i t •• t r i Ar oN ,, T'T.,., REMOTE OPERATED , 1"1" .,. . ! MASTER VALVE ""® rr iti' 4* iii sek �► IM Ss s. #,0; MANUAL. OPERATED MASTER VALVE riritirtirtistrit irretttew 41111=11116 ( Stinger d ipp MAPWRB. 1 1 _ _ VENT ,. 4--VALVE _ 7-4-7. J.! OPEN %�� 4� %t' Itil 11 — l'al� •, '� t Lt 'al"s si, FLOW TEE AND '70 VENT VALVE WELLHEAD rJ tt' tilttsim Atli VALVES %1nll //... OPEN ry Nilk ' ' /:: d! WELLHEAD " VALVES a r . CLOSED .---' -1' 741.. ' i1.�l ' � OUAD PACKOFF }moi. 'L ASSEMBLY IN PLACE IN TUBING I .,-a;" �'1.. TUBING b: • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm • - '/?/5. CD5-05 Additional Information: Updated to include !ower confining zone data CONFINING 9 DATA FOR FRACTURING ZONE AND CON IN NG ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 11114.99' MD/7407.78' TVDSS. The estimated fracture gradient for the Alpine A is 12.5 PPg. The overlying confining zone consists of over 600' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 9704.59' MD/6872.57' TVDSS. The underlying confining zone consists of approximately 1800' of Kingak shales. The estimated fracture gradient for the Kingak shales is 15-18 ppg. Fracture gradient increases down section. The top of the Kingak interval ranges from —7470' TVDSS at the heel to —7525' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-05 wellbore). i SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick,at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 11114.99' MD/7407.78' TVDSS. The estimated fracture gradient for the Alpine A is 12.5 ppg. The overlying confining zone consists of over 600' TVD of Miluv; ch, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveac s 15 ppg. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kal .ik and the HRZ is 16 ppg. Top HRZ was encountered at 9704.59' MD/6872.57' TVDSS. Jc 1 • • e0 co oz - - k9 E ` - ) i Is 4-7, 111 ki { & 3 } (§ \ 8 ) j k ) ( § { NI \ I k q a J .t. # Cl {} a }k \ } R . — — - a) a .- 0 , a) . CC La— o f } \ a co 2 --E- - s $ ) Q ] - § < Pa E 0 CCS /} � / \ a 4-4 & $ _ k _ _ /\ § CO/ co—oa / u_ } § \ \ / i- ; G \ \ -in f \ \ £ « In 4 Dl 4 ; < \ ( Lrl } In en na .11 � /o , § U K u • • 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: CD2-33: 9-5/8" casing cement pump report on 8/24/2001 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Slight returns were seen. The plug bumped at 1,200 psi and the floats were checked and they held. CD5-04: 7-5/8" casing cement pump report on 6/10/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 900 psi and the floats were checked and they held. CD5-03: The 7-5/8" cement report on 11/2/2015 shows that the cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.1 ppg LSND. No returns were seen. The plug bumped at 320 psi and the floats were checked and they held. CD5-315: The 7-5/8" casing cement pump report on 10/3/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug did not bump and the floats held, and pressure was held on the cement. CD5-315PB1: CD5-313PB1 was plugged and abandoned per state regulations on 9/24/2015 CD5-313: The 7-5/8" casing cement pump report on 7/25/2015. Full returns were not seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 11.1 ppg LSND. The plug bumped at 1,140 psi and the floats held. CD5-313PB1: CD5-313PB1 was plugged and abandoned per state regulations on 7/14/2015. • • - - I /,/l(' 443 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) Questions 3 & 4 CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there are three faults or fractures that transect the Alpine A formation and may enter the confining zone within one half mile radius of the wellbore trajectory for CD5- 05. The longer fault, projected to intersect the CD5-05 wellbore on the map, was not encountered within the well and must tip out to the west. In addition to this fault, there are two smaller faults that tip out within the half mile radius of the CD5-05. There were no lost circulated events encountered in the CD5-05. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. There are no faults that would intersect the fracture wings of the CD5-05 wellbore. Questions 0 If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Questions 1, 2, & 3 Drilled Faults Vertical Nearest Estimated Distance Well Depth Depth Loss Displacement Frac Port Propped XF from Name MD (ft) TVDSS (ft) (ft) (bbls/hr) (ft MD) (ft) fault (ft) CD5-05 no faults intersected CD2-33 no faults intersected • CD5-04 no faults intersected • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL' DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT TI 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 are three faults or fractures that transect the Alpine A formation and mAy enter the confining zone within one half mile radius of the wellbore trajectory for CD5-05. The longer fault, projected to intersect the CD5-05 wellbore on the map, was not encountered within the well and must tip out to the west. In addition to this fault, there are two smaller faults that tip out within the half mile radius of the CD5-05. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. W • ConocoPhillips Pia::Analysis Ala°aka '.2.131;15 ctiv cool .� r5 C9 175' G' !A" :rd offr Legend — Faults within Rants REFERENCE:•: Wel Data: ::7 i ps f..I3£1+.a We Data=3_e CCc_ — 'ir'ellsin112mi.Radius afOpenSean- S-race'Fac.ries:PLMit=ad=t,t-shec78'Cg r'? — Well in 12 mi.Radius of Teajectery ® Opp Secton f, — Well Tra/ectary /1■i Y C C.15 0 3 3.45 C.5 CD5-06open&w Amies O112 Mie Radius ! ! SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-05 was completed in 2015 as a horizontal producer in the Alpine A formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 1000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 300 bbl breakdown stage (25# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. • 24 bbls Linear Pad • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 1 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • • • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 2 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 3 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 4 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 5 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball6 • 300 bbls HYBOR G Pad • • • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 7 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 8 • 340 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 110 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/6 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 7 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 9 • 400 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 110 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 7 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 8 ppa 16/20 Carbolite • Flush with 114bbls of linear fluid protect • Total Sand: Approx: 925,000 lbs 16/20 Carbolite Note due to time constraints the hydraulic fracturing treatment might get split into 2 days of pumping. 11. 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O y , , , a 7S£ZL-4'LS£Zl @ d.41.4ZLll-6'lZLllP 0 2 Pun V Pu=S V LL V 6 IcAMul 0l lenialuI 0 C 0 U • Hydraulic Fracturing Fluid Product CompoInformation Disclosure •;.,Fracture Date. 2015-12-10 State: Alaska County:: Harrison Bay API Number: 5010320712 CONOCO PHILLIPS NORTH SLOPE Operator Name: EBUS Well Name and Number: CD5-05 Longitude:: -151.22 Latitude: 70.31 Long/Lat Projection: Production Type: True Vertical Depth(TVD): 7,529 Total Water Volume(gal)`: 389,905 Hydraulic Fracturing Fluid Composition: Chemical Maximum `'" Abstract Maximum Ingredient Ingredient " Ingredient Mass Trade Name Supplier'' Purpose Ingredients Service Concentration in Concentration in lbs Comments Number(CAS Additive(%by mass)** HF Fluid(%by #) mass)** Sea Water Operator Base Fluid NA NA 100.00= 77.85506-, 3320778 Density=8.540 BA-20 BUFFERING AGENT,BE-6 MICROBIOCIDE, Additive,Biocide, CL-22 UC,CL-31 Breaker,Buffer, CROSSLINKER, rker,Gelling LOSURF-3000, HalliburtonAgent,Crosnl Micr,Gellide, NA NA0 NA MO-67,OPTIFLO- Non-ionic Surfactant, III DELAYED RELEASE pH Control Additive BREAKER,SP BREAKER,WG-36 GELLING AGENT CarboLite 16/20 CarboCeramics Proppant NA NA0 NA 1,2,4 Trimethylbenzene - 95-63-6 1.00% 0.00069% 30 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00138% 59 Acetic acid 64-19-7 30.00% 0.00502% 215 Denise Tuck, Halliburton,3000 Acrylate polymer Confidential 1.00% 0.00093% 40 N.Sam Houston Pkwy E., Houston, TX 77032,281- 871-6226 Ammonium acetate 631-61-8 100.00% 0.01674% 717. Ammonium persulfate 7727-54-0 100.00% 0.01824% 780 Bentonite,benzyl(hydrogenated tallow alkyl)dimethylammonium 121888-68-4 5.00% 0.01140% 488 stearate complex Borate salts Confidential 60.00% 0.05572% 2383 Ceramic materials and wares, 66402-68-4 100.00% 21.62018% 924672 chemicals Crystalline silica,quartz 14808-60-7 30.00% 0.00556% 238 Crystalline Silica,Quartz 14808-60-7 0.10% 0.00023%. 10 Cured acrylic resin - Confidential 30.00 0.00547% 234 Ethanol 64-17-5 60.00* 0.04114% 1760 Guar gum 9000-30-0 100.00% 0.22792% 9748 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02057% 880 Naphthalene 91-20-3 5.00% 0.00343% 147 Oxyalkylated phenolic resin Confidential 30.00% 0.02743% 1174 Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00343% 147 branched Potassium formate 590-29-4 60.00% 0.05572% 2383 Potassium hydroxide 1310-58-3 5.00% 0.00144% 62 Potassium metaborate 13709-94-9 60.00% 0.01730% 740 Silica gel 112926-00-8 1.00% 0.00228% 98 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00093% 40 Sodium chloride 7647-14-5 1.00% 0.00163% 70 Sodium glycollate 2836-32-0 1.00% 0.00093% 40 Sodium hydroxide 1310-73-2 30.00% 0.02093% 896 Sodium persulfate 7775-27-1 100.00% 0.00044% 19 Sodium sulfate 7757-82-6 0.10% 0..00000% 1 Surfactant mixture Confidential 1.00% 0.00456%.. 196 Water 7732-18-5 100.00% 0-1.1995% 5132 Total Water Volume sources may include fresh water,produced water,and/or recycled water ""Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets(MSDS).As such,the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's(OSHA)regulations govern the criteria for the disclosure of this information.Please note that Federal Law protects"proprietary","trade secret",and"confidential business information"and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i)and Appendix D. • • TD Q o CD 2 c U a. co (6 < U- LO ' N Oco oP U • • C IV4 u Z. e rwti r ` 0 d RI 4 0 0 • `r' el et r*a raa e c c r^-a O• C ,. s... a . epi c ret *t 0 C , 0') i 0 0 'i i°"-a ria ra r1 r°i _ ...4 .-t. C (3. 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'�/ Up — — 1E O fn u) Cll O O cn wo c o I cv•LI • • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) . . Lo e,, a) N 4. OJ CO CO CO CO CO CO m m co 1-- E a a a CL O. a aa.. a U U a > U U U U U U L i^ O co t. U c 0 ' co O U c N I O o 4., z. ' . i t N 5. mom M � ooE •� o a c Z v $ .r w- co 0 V o o CO 3 ,�' !p Q) 0 a `^,., a � v, o Z a 0 �• � a, @Up9 0- -c c , c 'o� a I. � U a-i ` ill 'Cv, -° Q- p a) Q), O L N Q , , C o4- c ! � co %-i •�, UaO M 3 oo +O N O C f ° 3 °I " -o V = a 0 o - c R ..... O c ° o' •`-' ti °' a vao a -9 L co ++ 0 cu 2 co m _ E 0 a- 15 + iv,V a) Z O aJ vi v, oc -n � c u = v, ° = c ca) 0. 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Es: of d a_ u •— Ln CO O' 'a = v a, o O O 01 i + i' 4„ "0 0 a, a E a ' IA c °° 025V O i .c v -0 CT i v,„ sa)..0a fa; i 0 m reO' 4.4 O0 ‘A ' uO x 'a C H CO U tib °zov a ° �'! c N °' oa '� ° _ aoo v 2 1 o.a, LnQ d o Zo V U V aQ a 't3 C,I G! a IA '- Z a. va. �O +' '� a z ° o u = CD a,a, Q J 0 cc a c ! a jLa QJ 0 IA 4 E a `�$ -a c o aV v, n '. v + a ° Oi 'a u, aQ a ' ZH "' 'p r. $ u°Z v, °p no aovQ h Q oL CL °N z L y; uZiv e, +' u c Nv 0o � C Of Op > W a -- CL, ....1 v ti ` a n � p .... c) U H a IL v I u ., a, c CC c v c c, 'o y `ti a `! v '' o 'a 0 1- 04---t0 s ,.. d i 00 `� a O v a y i v a5 v IN 'OQ • "' cc a.. acro > ° v Q • • Bettis, Patricia K (DOA) From: Blakney, Robert G <Robert.G.Blakney@conocophillips.com> Sent: Thursday, January 07, 2016 11:24 AM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD5-05 PTD No. 215-073: Hydraulic Fracturing Sundry Application Attachments: CD5-05 questions.docx Patricia, Attached is the updated information you requested for CD5-05. Please let me know if you have any questions or need any additional information. Thanks, -Robbie P.S. I assume you'll have the same questions for the CD5-04 sundry application we submitted, so I'll send that information over to you later today. Robert Blakney ConocoPhillips Senior Completions Engineer 907 -265 -6417 (office) 505—804 - 5246 (cell) ATO 1740, 700 G st. Anchorage, AK From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, January 06, 2016 2:08 PM To: Blakney, Robert G Subject: [EXTERNAL]CRU CD5-05 PTD No. 215-073: Hydraulic Fracturing Sundry Application Good afternoon Robert, Additional information request: 1. Please provide a list of fault-cuts (MD,TVDSS and vertical displacement)that have been observed within wells and well branches within and near the AOR. If no fault cuts have been observed, please state so. 2. Discuss any occurrences of lost circulation in those wells and well branches that occurred while drilling. 3. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 4. Discuss the thickness and competence of the top seal for the Alpine Pool within the AOR and how any faults within the AOR that cut this top seal will not affect the ability of that top seal to confine injected fluids to the pool. 1 • . 5. Please discuss any mitigation plans ConocoPhillips may have should any of the fracture wings appear to intersect a fault during fracturing operations. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday,January 06, 2016 11:11 AM To: Blakney, Robert G (Robert.G.Blakney@conocophillips.com) Subject: CRU CD5-05 (PTD No. 215-073): Hydraulic Facture Sundry Application Good morning Robert, In Section 9-Data For Fracturing Zone and Confining Zones 20 AAC 25.283(a)(9), ConocoPhillips providing information for the upper confining zones for the Alpine A sandstone. Please provide a description of the lower confining zone, formation name, thickness, depth (MD and TVDss), and fracture gradient. 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 • • Guhl, Meredith D (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Monday, November 02, 2015 3:40 PM To: Guhl, Meredith D (DOA) Subject: RE:CRU C5-05, PTD 215-073, Complete list of Geologic Markers Attachments: CD5-05_tops.xlsx Meredith, Attached please find a list of all the tops for CD5-05.We will plan on submitting these 12 markers(if present, and others that are present) in all the CD5 wells moving forward. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 From: Guhl, Meredith D (DOA) [mailto:meredith.guhlOalaska.gov] Sent: Friday, October 30, 2015 3:09 PM To: Earhart, Will C Subject: [EXTERNAL]FW: CRU C5-05, PTD 215-073, Complete list of Geologic Markers Will, During a review of the 10-407 form submitted for CRU C5-05, PTD 215-073,completed 9/8/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by November 13, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 1 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • i Top Actual MD Actual TVD Actual TVDSSI C30 2494.73 2323.34 -2252.74 K3 4733.96 3779.15 -3708.55 K2 5099.98 4013.3 -3942.7 Albian 97 5756.88 4433.32 -4362.72 Albian 96 7749.42 5705.9 -5635.3 HRZ(FCS) 9704.59 6943.17 -6872.57 Kalubik (Base HRZ) 10077.45 7156.63 -7086.03 Kuparuk C 10294.04 7267.58 -7196.98 LCU/ Miluveach 10303.14 7271.92 -7201.32 Alpine C 10664.2 7403.84 -7333.24 UJU 10665.64 7404.2 -7333.6 Alpine A 11114.99 7475.38 -7404.78 A , _. • 210 "13 • 26315 OCT 0 8 2015 chiumberger AOGCC Transmittal#: 080CT15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery N`1OK/BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-05 Date Dispatched: 8-Oct-15 Job#: 15AKA0024 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2'TVD x x Scope Resistivity 5'MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a)conocophillips.com AlaskaPTSPrintCentera@slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: fi),Ahredi49.117) ..P� • • 215073 26315 OCT 08 2015 AOGCC FINAL � J NADConversion Western North Slope CD5 Alpine West Pad CD5-05 Definitive Survey Report 24 September, 2015 NAD 27 110 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-05 Well Position +N/-S 0.00 usft Northing: 5,965,893.83 usfi Latitude: 70° 18'50.136 N +E/-W 0.00 usft Easting: 349,462.32 usfi Longitude: 151° 13'12.298 W' Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 34.30 usft Wellbore CD5-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/14/2015 18.06 80.83 57,473 Design CD5-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 152.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.40 1,006.40 CD5-05 Srvy#1 -GYD-GC-MS(CD5-05) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 10:52 1,036.18 2,233.29 CD5-05 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:35 2,321.66 11,125.15 CD5-05 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:4C 11,219.18 17,458.41 CD5-05 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/10/2015 11:2 17,900.00 17,900.00 CD5-05 Srvy#5-Blind Surveys to TD(C BLIND Blind drilling 9/23/2015 3:5 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.70 0.00 0.00 36.70 -34.30 0.00 0.00 5,965,893.83 349,462.32 0.00 0.00 UNDEFINED 115.50 0.09 323.04 115.50 44.50 0.05 -0.04 5,965,893.89 349,462.28 0.12 -0.06 GYD-GC-MS(1) NOT an Actual Survey 20"x 42" 170.00 0.16 323.04 170.00 99.00 0.15 -0.11 5,965,893.98 349,462.21 0.12 -0.18 GYD-GC-MS(1) 261.00 0.24 319.82 261.00 190.00 0.40 -0.31 5,965,894.24 349,462.01 0.09 -0.50 GYD-GC-MS(1) 352.00 0.53 32.27 352.00 281.00 0.90 -0.21 5,965,894.73 349,462.12 0.56 -0.89 GYD-GC-MS(1) 446.00 1.36 2.78 445.98 374.98 2.38 0.08 5,965,896.21 349,462.44 1.00 -2.06 GYD-GC-MS(1) 537.00 2.80 4.18 536.92 465.92 5.67 0.29 5,965,899.50 349,462.72 1.58 -4.87 GYD-GC-MS(1) 629.00 3.45 359.33 628.78 557.78 10.68 0.42 5,965,904.51 349,462.95 0.76 -9.23 GYD-GC-MS(1) 724.00 4.42 351.29 723.56 652.56 17.16 -0.17 5,965,910.99 349,462.49 1.17 -15.23 GYD-GC-MS(1) 817.00 6.30 346.15 816.15 745.15 25.66 -1.93 5,965,919.52 349,460.90 2.08 -23.56 GYD-GC-MS(1) 9/24/2015 8:40:40AM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 912.00 8.23 349.75 910.38 839.38 37.41 -4.39 5,965,931.32 349,458.68 2.09 -35.09 GYD-GC-MS(1) 1,006.00 10.18 357.54 1,003.17 932.17 52.33 -5.94 5,965,946.27 349,457.42 2.46 -49.00 GYD-GC-MS(1) 1,036.18 10.17 358.79 1,032.88 961.88 57.66 -6.11 5,965,951.60 349,457.36 0.73 -53.78 MWD+IFR-AK-CAZ-SC(2) 1,128.82 11.64 6.28 1,123.85 1,052.85 75.13 -5.26 5,965,969.05 349,458.56 2.20 -68.81 MWD+IFR-AK-CAZ-SC(2) 1,222.78 12.43 11.54 1,215.74 1,144.74 94.46 -2.20 5,965,988.31 349,462.01 1.44 -84.44 MWD+IFR-AK-CAZ-SC(2) 1,317.28 13.55 18.16 1,307.83 1,236.83 114.95 3.28 5,966,008.68 349,467.90 1.97 -99.95 MWD+IFR-AK-CAZ-SC(2) 1,412.02 14.94 23.33 1,399.66 1,328.66 136.71 11.58 5,966,030.27 349,476.63 1.99 -115.27 MWD+IFR-AK-CAZ-SC(2) 1,506.57 17.49 28.05 1,490.44 1,419.44 160.44 23.09 5,966,053.77 349,488.62 3.03 -130.82 MWD+IFR-AK-CAZ-SC(2) 1,601.60 21.14 33.82 1,580.12 1,509.12 187.29 39.35 5,966,080.29 349,505.41 4.33 -146.90 MWD+IFR-AK-CAZ-SC(2) 1,694.39 24.51 40.27 1,665.64 1,594.64 215.89 61.11 5,966,108.44 349,527.74 4.52 -161.93 MWD+IFR-AK-CAZ-SC(2) 1,788.17 26.97 47.23 1,750.13 1,679.13 245.19 89.31 5,966,137.16 349,556.52 4.15 -174.56 MWD+IFR-AK-CAZ-SC(2) 1,882.93 29.89 50.21 1,833.46 1,762.46 274.90 123.23 5,966,166.18 349,591.03 3.43 -184.86 MWD+IFR-AK-CAZ-SC(2) 1,976.74 32.10 52.36 1,913.87 1,842.87 305.08 160.94 5,966,195.61 349,629.33 2.63 -193.82 MWD+IFR-AK-CAZ-SC(2) 2,071.48 34.09 55.30 1,993.24 1,922.24 335.58 202.71 5,966,225.25 349,671.69 2.70 -201.13 MWD+IFR-AK-CAZ-SC(2) 2,165.46 37.01 60.36 2,069.71 1,998.71 364.57 248.97 5,966,253.31 349,718.52 4.41 -205.01 MWD+IFR-AK-CAZ-SC(2) 2,233.29 37.32 61.67 2,123.77 2,052.77 384.42 284.81 5,966,272.44 349,754.75 1.25 -205.72 MWD+IFR-AK-CAZ-SC(2) 2,267.00 37.96 62.04 2,150.46 2,079.46 394.13 302.96 5,966,281.78 349,773.09 2.01 -205.77 MWD+IFR-AK-CAZ-S NOT an Actual Sun 10 3/4"x 13-1/2 2,321.66 38.99 62.63 2,193.25 2,122.25 409.92 333.08 5,966,296.96 349,803.52 2.01 -205.57 MWD+IFR-AK-CAZ-SC(3) 2,416.38 41.33 64.20 2,265.64 2,194.64 437.24 387.71 5,966,323.18 349,858.68 2.69 -204.04 MWD+IFR-AK-CAZ-SC(3) 2,511.56 43.80 66.43 2,335.74 2,264.74 464.09 446.21 5,966,348.85 349,917.71 3.04 -200.29 MWD+IFR-AK-CAZ-SC(3) 2,604.77 46.31 68.70 2,401.59 2,330.59 489.24 507.19 5,966,372.77 349,979.17 3.20 -193.86 MWD+IFR-AK-CAZ-SC(3) 2,699.24 49.00 70.31 2,465.22 2,394.22 513.66 572.59 5,966,395.87 350,045.04 3.11 -184.72 MWD+IFR-AK-CAZ-SC(3) 2,794.92 49.85 71.33 2,527.45 2,456.45 537.53 641.23 5,966,418.36 350,114.14 1.20 -173.57 MWD+IFR-AK-CAZ-SC(3) 2,888.60 49.90 71.50 2,587.82 2,516.82 560.36 709.12 5,966,439.82 350,182.48 0.15 -161.86 MWD+IFR-AK-CAZ-SC(3) 2,982.11 49.80 73.33 2,648.12 2,577.12 581.95 777.25 5,966,460.05 350,251.02 1.50 -148.94 MWD+IFR-AK-CAZ-SC(3) 3,076.74 49.97 70.94 2,709.10 2,638.10 604.15 846.12 5,966,480.86 350,320.32 1.94 -136.21 MWD+IFR-AK-CAZ-SC(3) 3,170.90 49.73 72.56 2,769.81 2,698.81 626.69 914.47 5,966,502.02 350,389.10 1.34 -124.02 MWD+IFR-AK-CAZ-SC(3) 3,265.24 49.72 71.99 2,830.80 2,759.80 648.61 983.03 5,966,522.55 350,458.08 0.46 -111.18 MWD+IFR-AK-CAZ-SC(3) 3,359.73 49.95 71.86 2,891.75 2,820.75 671.01 1,051.67 5,966,543.58 350,527.15 0.27 -98.74 MWD+IFR-AK-CAZ-SC(3) 3,453.39 49.75 71.77 2,952.14 2,881.14 693.35 1,119.69 5,966,564.55 350,595.59 0.23 -86.53 MWD+IFR-AK-CAZ-SC(3) 3,546.76 49.90 72.43 3,012.37 2,941.37 715.28 1,187.57 5,966,585.11 350,663.90 0.56 -74.02 MWD+IFR-AK-CAZ-SC(3) 3,641.22 49.75 74.33 3,073.31 3,002.31 735.92 1,256.73 5,966,604.36 350,733.45 1.55 -59.78 MWD+IFR-AK-CAZ-SC(3) 3,735.79 49.74 74.74 3,134.43 3,063.43 755.17 1,326.29 5,966,622.20 350,803.38 0.33 -44.12 MWD+IFR-AK-CAZ-SC(3) 3,829.64 49.91 74.89 3,194.97 3,123.97 773.95 1,395.49 5,966,639.59 350,872.94 0.22 -28.21 MWD+IFR-AK-CAZ-SC(3) 3,923.73 49.92 74.79 3,255.56 3,184.56 792.78 1,464.98 5,966,657.02 350,942.78 0.08 -12.22 MWD+IFR-AK-CAZ-SC(3) 4,017.51 49.68 73.43 3,316.09 3,245.09 812.39 1,533.86 5,966,675.24 351,012.04 1.14 2.81 MWD+IFR-AK-CAZ-SC(3) 4,112.34 49.76 72.59 3,377.40 3,306.40 833.52 1,603.05 5,966,694.99 351,081.64 0.68 16.63 MWD+IFR-AK-CAZ-SC(3) 4,204.12 49.61 70.91 3,436.78 3,365.78 855.44 1,669.51 5,966,715.57 351,148.51 1.41 28.48 MWD+IFR-AK-CAZ-SC(3) 4,298.05 49.84 68.99 3,497.51 3,426.51 880.01 1,736.82 5,966,738.78 351,216.30 1.58 38.39 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 8:40:40AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,391.45 49.53 69.34 3,557.94 3,486.94 905.34 1,803.38 5,966,762.77 351,283.35 0.44 47.27 MWD+IFR-AK-CAZ-SC(3) 4,485.11 49.65 69.82 3,618.65 3,547.65 930.22 1,870.22 5,966,786.30 351,350.67 0.41 56.68 MWD+IFR-AK-CAZ-SC(3) 4,579.23 49.53 69.74 3,679.67 3,608.67 954.99 1,937.47 5,966,809.72 351,418.39 0.14 66.38 MWD+IFR-AK-CAZ-SC(3) 4,670.60 50.15 70.59 3,738.59 3,667.59 978.68 2,003.15 5,966,832.09 351,484.54 0.98 76.30 MWD+IFR-AK-CAZ-SC(3) 4,764.58 50.24 70.57 3,798.76 3,727.76 1,002.69 2,071.24 5,966,854.72 351,553.09 0.10 87.07 MWD+IFR-AK-CAZ-SC(3) 4,859.68 50.24 71.51 3,859.58 3,788.58 1,026.44 2,140.38 5,966,877.08 351,622.68 0.76 98.56 MWD+IFR-AK-CAZ-SC(3) 4,952.93 50.24 70.61 3,919.22 3,848.22 1,049.70 2,208.18 5,966,898.98 351,690.93 0.74 109.84 MWD+IFR-AK-CAZ-SC(3) 5,048.19 50.17 70.77 3,980.19 3,909.19 1,073.91 2,277.26 5,966,921.79 351,760.47 0.15 120.90 MWD+IFR-AK-CAZ-SC(3) 5,141.18 50.36 71.07 4,039.64 3,968.64 1,097.28 2,344.84 5,966,943.81 351,828.51 0.32 131.99 MWD+IFR-AK-CAZ-SC(3) 5,235.58 50.25 71.96 4,099.93 4,028.93 1,120.31 2,413.73 5,966,965.45 351,897.84 0.73 144.00 MWD+IFR-AK-CAZ-SC(3) 5,330.57 50.20 72.22 4,160.70 4,089.70 1,142.76 2,483.19 5,966,986.50 351,967.74 0.22 156.79 MWD+I FR-AK-CAZ-SC(3) 5,424.99 50.21 72.10 4,221.13 4,150.13 1,164.99 2,552.25 5,967,007.34 352,037.22 0.10 169.59 MWD+IFR-AK-CAZ-SC(3) 5,518.94 50.38 72.00 4,281.15 4,210.15 1,187.26 2,621.01 5,967,028.23 352,106.41 0.20 182.20 MWD+IFR-AK-CAZ-SC(3) 5,612.48 50.32 71.00 4,340.84 4,269.84 1,210.12 2,689.31 5,967,049.70 352,175.15 0.83 194.09 MWD+IFR-AK-CAZ-SC(3) 5,706.88 50.06 72.28 4,401.28 4,330.28 1,232.96 2,758.13 5,967,071.16 352,244.41 1.08 206.23 MWD+I FR-AK-CAZ-SC(3) 5,800.90 50.22 73.11 4,461.54 4,390.54 1,254.43 2,827.04 5,967,091.24 352,313.72 0.70 219.62 MWD+I FR-AK-CAZ-SC(3) 5,894.93 50.54 74.11 4,521.50 4,450.50 1,274.86 2,896.52 5,967,110.28 352,383.60 0.89 234.20 MWD+IFR-AK-CAZ-SC(3) 5,988.68 50.75 72.19 4,580.96 4,509.96 1,295.87 2,965.89 5,967,129.89 352,453.37 1.60 248.21 MWD+IFR-AK-CAZ-SC(3) 6,083.86 50.87 72.59 4,641.10 4,570.10 1,318.19 3,036.21 5,967,150.79 352,524.11 0.35 261.52 MWD+I FR-AK-CAZ-SC(3) 6,177.29 50.83 72.79 4,700.09 4,629.09 1,339.75 3,105.38 5,967,170.96 352,593.70 0.17 274.96 MWD+I FR-AK-CAZ-SC(3) 6,271.84 50.23 72.22 4,760.19 4,689.19 1,361.69 3,174.99 5,967,191.50 352,663.73 0.79 288.27 MWD+I FR-AK-CAZ-SC(3) 6,366.56 50.36 71.43 4,820.70 4,749.70 1,384.42 3,244.23 5,967,212.83 352,733.40 0.66 300.70 MWD+IFR-AK-CAZ-SC(3) 6,461.05 50.13 69.81 4,881.13 4,810.13 1,408.52 3,312.75 5,967,235.56 352,802.39 1.34 311.59 MWD+I FR-AK-CAZ-SC(3) 6,554.50 50.13 70.54 4,941.04 4,870.04 1,432.85 3,380.22 5,967,258.52 352,870.33 0.60 321.79 MWD+IFR-AK-CAZ-SC(3) 6,650.30 50.14 71.55 5,002.44 4,931.44 1,456.73 3,449.76 5,967,281.00 352,940.33 0.81 333.35 MWD+IFR-AK-CAZ-SC(3) 6,744.34 50.21 72.02 5,062.67 4,991.67 1,479.31 3,518.37 5,967,302.20 353,009.37 0.39 345.62 MWD+IFR-AK-CAZ-SC(3) 6,838.05 50.10 71.80 5,122.71 5,051.71 1,501.65 3,586.76 5,967,323.16 353,078.19 0.22 358.00 MWD+I FR-AK-CAZ-SC(3) 6,933.37 50.18 72.15 5,183.81 5,112.81 1,524.29 3,656.34 5,967,344.40 353,148.20 0.29 370.68 MWD+I FR-AK-CAZ-SC(3) 7,026.40 50.20 71.27 5,243.37 5,172.37 1,546.72 3,724.19 5,967,365.46 353,216.49 0.73 382.73 MWD+I FR-AK-CAZ-SC(3) 7,121.17 50.30 70.01 5,303.97 5,232.97 1,570.87 3,792.93 5,967,388.23 353,285.69 1.03 393.68 MWD+IFR-AK-CAZ-SC(3) 7,214.11 50.20 68.99 5,363.40 5,292.40 1,595.89 3,859.86 5,967,411.91 353,353.11 0.85 403.00 MWD+I FR-AK-CAZ-SC(3) 7,310.65 50.15 68.43 5,425.23 5,354.23 1,622.81 3,928.94 5,967,437.43 353,422.71 0.45 411.67 MWD+IFR-AK-CAZ-SC(3) 7,404.66 50.05 69.36 5,485.53 5,414.53 1,648.78 3,996.22 5,967,462.05 353,490.49 0.77 420.32 MWD+IFR-AK-CAZ-SC(3) 7,499.39 50.09 70.39 5,546.34 5,475.34 1,673.78 4,064.43 5,967,485.67 353,559.18 0.83 430.28 MWD+IFR-AK-CAZ-SC(3) 7,592.46 50.37 70.70 5,605.87 5,534.87 1,697.60 4,131.88 5,967,508.13 353,627.09 0.40 440.91 MWD+IFR-AK-CAZ-SC(3) 7,687.75 50.33 71.48 5,666.68 5,595.68 1,721.38 4,201.29 5,967,530.51 353,696.96 0.63 452.50 MWD+IFR-AK-CAZ-SC(3) 7,781.73 50.67 71.21 5,726.46 5,655.46 1,744.57 4,269.99 5,967,552.32 353,766.11 0.42 464.27 MWD+I FR-AK-CAZ-SC(3) 7,876.29 50.48 70.96 5,786.51 5,715.51 1,768.25 4,339.09 5,967,574.61 353,835.66 0.29 475.81 MWD+I F R-AK-CAZ-SC(3) 7,970.75 50.41 70.55 5,846.66 5,775.66 1,792.26 4,407.85 5,967,597.23 353,904.89 0.34 486.89 MWD+I FR-AK-CAZ-SC(3) 8,065.19 51.14 71.43 5,906.38 5,835.38 1,816.08 4,477.02 5,967,619.66 353,974.51 1.06 498.33 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 8:40:40AM Page 4 COMPASS 5000.1 Build 74 SSchlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 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 8,158.89 51.02 72.20 5,965.25 5,894.25 1,838.84 4,546.28 5,967,641.02 354,044.21 0.65 510.75 MWD+IFR-AK-CAZ-SC(3) 8,252.93 51.07 72.38 6,024.37 5,953.37 1,861.08 4,615.94 5,967,661.86 354,114.30 0.16 523.82 MWD+IFR-AK-CAZ-SC(3) 8,347.58 51.09 73.00 6,083.84 6,012.84 1,882.99 4,686.25 5,967,682.36 354,185.02 0.51 537.48 MWD+IFR-AK-CAZ-SC(3) 8,440.63 50.54 74.04 6,142.63 6,071.63 1,903.45 4,755.41 5,967,701.43 354,254.57 1.05 551.88 MWD+IFR-AK-CAZ-SC(3) 8,535.48 50.09 74.21 6,203.20 6,132.20 1,923.42 4,825.62 5,967,719.98 354,325.16 0.49 567.21 MWD+IFR-AK-CAZ-SC(3) 8,630.19 50.11 74.83 6,263.95 6,192.95 1,942.81 4,895.64 5,967,737.97 354,395.55 0.50 582.96 MWD+IFR-AK-CAZ-SC(3) 8,725.00 49.89 74.44 6,324.89 6,253.89 1,962.06 4,965.67 5,967,755.80 354,465.95 0.39 598.85 MWD+IFR-AK-CAZ-SC(3) 8,819.59 49.87 75.44 6,385.84 6,314.84 1,980.85 5,035.52 5,967,773.19 354,536.16 0.81 615.04 MWD+IFR-AK-CAZ-SC(3) 8,914.57 50.69 76.23 6,446.54 6,375.54 1,998.73 5,106.35 5,967,789.64 354,607.33 1.07 632.52 MWD+IFR-AK-CAZ-SC(3) 9,008.49 50.68 74.31 6,506.05 6,435.05 2,017.20 5,176.62 5,967,806.70 354,677.95 1.58 649.19 MWD+IFR-AK-CAZ-SC(3) 9,102.83 50.79 71.58 6,565.77 6,494.77 2,038.62 5,246.44 5,967,826.71 354,748.18 2.24 663.06 MWD+IFR-AK-CAZ-SC(3) 9,198.29 50.80 68.86 6,626.11 6,555.11 2,063.65 5,316.03 5,967,850.34 354,818.26 2.21 673.63 MWD+IFR-AK-CAZ-SC(3) 9,291.98 50.55 68.58 6,685.49 6,614.49 2,089.95 5,383.57 5,967,875.28 354,886.30 0.35 682.11 MWD+IFR-AK-CAZ-SC(3) 9,386.31 50.39 70.25 6,745.53 6,674.53 2,115.53 5,451.67 5,967,899.49 354,954.90 1.38 691.50 MWD+IFR-AK-CAZ-SC(3) 9,480.79 51.05 74.42 6,805.36 6,734.36 2,137.70 5,521.33 5,967,920.26 355,024.98 3.49 704.63 MWD+IFR-AK-CAZ-SC(3) 9,528.99 51.04 78.17 6,835.67 6,764.67 2,146.58 5,557.73 5,967,928.40 355,061.55 6.05 713.88 MWD+IFR-AK-CAZ-SC(3) 9,574.71 51.36 80.61 6,864.32 6,793.32 2,153.14 5,592.75 5,967,934.26 355,096.69 4.22 724.53 MWD+IFR-AK-CAZ-SC(3) 9,620.96 51.95 82.82 6,893.02 6,822.02 2,158.36 5,628.64 5,967,938.76 355,132.68 3.96 736.77 MWD+IFR-AK-CAZ-SC(3) 9,669.50 53.25 84.87 6,922.50 6,851.50 2,162.49 5,666.98 5,967,942.12 355,171.09 4.29 751.12 MWD+IFR-AK-CAZ-SC(3) 9,763.43 54.60 89.13 6,977.82 6,906.82 2,166.44 5,742.76 5,967,944.55 355,246.93 3.94 783.21 MWD+IFR-AK-CAZ-SC(3) 9,856.52 54.68 94.02 7,031.72 6,960.72 2,164.35 5,818.61 5,967,940.94 355,322.72 4.28 820.67 MWD+IFR-AK-CAZ-SC(3) 9,951.28 55.34 97.77 7,086.07 7,015.07 2,156.37 5,895.81 5,967,931.41 355,399.73 3.32 863.95 MWD+IFR-AK-CAZ-SC(3) 10,046.00 56.00 100.67 7,139.50 7,068.50 2,143.83 5,973.01 5,967,917.33 355,476.66 2.62 911.27 MWD+IFR-AK-CAZ-SC(3) 10,140.61 57.96 103.58 7,191.06 7,120.06 2,127.15 6,050.54 5,967,899.10 355,553.84 3.31 962.40 MWD+IFR-AK-CAZ-SC(3) 10,235.45 60.41 106.52 7,239.64 7,168.64 2,105.98 6,129.17 5,967,876.36 355,632.02 3.71 1,018.00 MWD+IFR-AK-CAZ-SC(3) 10,329.65 62.63 109.47 7,284.57 7,213.57 2,080.38 6,207.90 5,967,849.19 355,710.21 3.62 1,077.56 MWD+IFR-AK-CAZ-SC(3) 10,422.01 66.34 111.84 7,324.35 7,253.35 2,050.97 6,285.86 5,967,818.22 355,787.57 4.64 1,140.14 MWD+IFR-AK-CAZ-SC(3) 10,516.37 69.24 113.95 7,360.02 7,289.02 2,016.97 6,366.32 5,967,782.62 355,867.32 3.71 1,207.93 MWD+IFR-AK-CAZ-SC(3) 10,610.31 73.35 114.97 7,390.14 7,319.14 1,980.13 6,447.29 5,967,744.16 355,947.53 4.49 1,278.47 MWD+IFR-AK-CAZ-SC(3) 10,703.60 77.19 115.44 7,413.85 7,342.85 1,941.71 6,528.91 5,967,704.12 356,028.35 4.14 1,350.71 MWD+IFR-AK-CAZ-SC(3) 10,798.65 79.87 116.66 7,432.75 7,361.75 1,900.80 6,612.58 5,967,661.54 356,111.19 3.09 1,426.11 MWD+IFR-AK-CAZ-SC(3) 10,892.12 81.12 118.00 7,448.19 7,377.19 1,858.48 6,694.48 5,967,617.59 356,192.21 1.95 1,501.93 MWD+IFR-AK-CAZ-SC(3) 10,986.96 82.59 119.17 7,461.63 7,390.63 1,813.56 6,776.91 5,967,571.03 356,273.72 1.97 1,580.29 MWD+IFR-AK-CAZ-SC(3) 11,081.16 84.51 120.81 7,472.21 7,401.21 1,766.77 6,857.97 5,967,522.63 356,353.82 2.67 1,659.66 MWD+IFR-AK-CAZ-SC(3) 11,125.15 84.75 121.35 7,476.33 7,405.33 1,744.16 6,895.48 5,967,499.28 356,390.87 1.34 1,697.23 MWD+IFR-AK-CAZ-SC(3) 11,176.80 86.42 122.77 7,480.30 7,409.30 1,716.83 6,939.12 5,967,471.08 356,433.95 4.24 1,741.85 MWD+IFR-AK-CAZ-SC - NOT an Actual Sun 7-5/8"x 9-7/8" 11,219.18 87.79 123.93 7,482.44 7,411.44 1,693.56 6,974.48 5,967,447.11 356,468.83 4.24 1,778.99 MWD+IFR-AK-CAZ-SC(4) 11,315.42 88.69 126.50 7,485.40 7,414.40 1,638.10 7,053.06 5,967,390.08 356,546.28 2.83 1,864.86 MWD+IFR-AK-CAZ-SC(4) 11,411.53 89.55 129.95 7,486.88 7,415.88 1,578.64 7,128.54 5,967,329.13 356,620.54 3.70 1,952.79 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 8:40:40AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 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 11,459.09 89.71 132.83 7,487.18 7,416.18 1,547.20 7,164.22 5,967,296.98 356,655.58 6.06 1,997.30 MWD+IFR-AK-CAZ-SC(4) 11,504.67 90.34 136.47 7,487.16 7,416.16 1,515.18 7,196.64 5,967,264.32 356,687.35 8.10 2,040.80 MWD+IFR-AK-CAZ-SC(4) 11,554.31 89.34 139.42 7,487.30 7,416.30 1,478.32 7,229.89 5,967,226.81 356,719.85 6.27 2,088.94 MWD+I FR-AK-CAZ-SC(4) 11,600.60 90.23 141.69 7,487.48 7,416.48 1,442.58 7,259.29 5,967,190.48 356,748.53 5.27 2,134.31 MWD+IFR-AK-CAZ-SC(4) 11,696.04 90.03 143.62 7,487.26 7,416.26 1,366.71 7,317.19 5,967,113.47 356,804.89 2.03 2,228.48 MWD+IFR-AK-CAZ-SC(4) 11,791.92 89.89 146.70 7,487.33 7,416.33 1,288.02 7,371.95 5,967,033.71 356,858.06 3.22 2,323.67 MWD+I FR-AK-CAZ-SC(4) 11,887.57 90.27 150.03 7,487.19 7,416.19 1,206.60 7,422.12 5,966,951.30 356,906.58 3.50 2,419.11 MWD+IFR-AK-CAZ-SC(4) 11,982.10 90.00 154.27 7,486.97 7,415.97 1,123.04 7,466.27 5,966,866.88 356,949.04 4.49 2,513.62 MWD+I FR-AK-CAZ-SC(4) 12,077.59 90.37 155.68 7,486.66 7,415.66 1,036.51 7,506.66 5,966,779.57 356,987.69 1.53 2,608.98 MWD+IFR-AK-CAZ-SC(4) 12,173.12 90.56 154.55 7,485.89 7,414.89 949.86 7,546.86 5,966,692.13 357,026.14 1.20 2,704.36 MWD+I FR-AK-CAZ-SC(4) 12,268.08 89.71 154.72 7,485.66 7,414.66 864.05 7,587.53 5,966,605.54 357,065.08 0.91 2,799.22 MWD+IFR-AK-CAZ-SC(4) 12,363.92 89.86 154.69 7,486.02 7,415.02 777.40 7,628.48 5,966,518.09 357,104.29 0.16 2,894.95 MWD+I FR-AK-CAZ-SC(4) 12,459.34 89.41 154.35 7,486.63 7,415.63 691.27 7,669.53 5,966,431.15 357,143.60 0.59 2,990.28 MWD+IFR-AK-CAZ-SC(4) 12,554.74 89.11 155.88 7,487.86 7,416.86 604.73 7,709.67 5,966,343.84 357,181.99 1.63 3,085.52 MWD+IFR-AK-CAZ-SC(4) 12,650.39 88.93 155.18 7,489.50 7,418.50 517.69 7,749.29 5,966,256.02 357,219.85 0.76 3,180.98 MWD+I FR-AK-CAZ-SC(4) 12,745.68 89.45 156.75 7,490.85 7,419.85 430.67 7,788.09 5,966,168.25 357,256.90 1.74 3,276.03 MWD+IFR-AK-CAZ-SC(4) 12,840.55 89.77 156.28 7,491.49 7,420.49 343.66 7,825.90 5,966,080.51 357,292.95 0.60 3,370.60 MWD+I FR-AK-CAZ-SC(4) 12,936.09 89.13 157.80 7,492.41 7,421.41 255.70 7,863.16 5,965,991.82 357,328.44 1.73 3,465.76 MWD+IFR-AK-CAZ-SC(4) 13,031.28 89.38 156.49 7,493.65 7,422.65 167.99 7,900.13 5,965,903.40 357,363.64 1.40 3,560.56 MWD+IFR-AK-CAZ-SC(4) 13,126.49 89.45 156.43 7,494.62 7,423.62 80.71 7,938.15 5,965,815.38 357,399.90 0.10 3,655.48 MWD+IFR-AK-CAZ-SC(4) 13,221.98 88.93 156.35 7,495.97 7,424.97 -6.78 7,976.40 5,965,727.15 357,436.38 0.55 3,750.68 MWD+IFR-AK-CAZ-SC(4) 13,317.60 88.83 156.23 7,497.84 7,426.84 -94.31 8,014.84 5,965,638.87 357,473.06 0.16 3,846.01 MWD+IFR-AK-CAZ-SC(4) 13,412.85 88.80 155.70 7,499.81 7,428.81 -181.28 8,053.62 5,965,551.14 357,510.09 0.56 3,941.01 MWD+IFR-AK-CAZ-SC(4) 13,508.02 88.97 153.90 7,501.66 7,430.66 -267.38 8,094.14 5,965,464.26 357,548.86 1.90 4,036.05 MWD+IFR-AK-CAZ-SC(4) 13,603.36 89.76 154.02 7,502.72 7,431.72 -353.03 8,135.99 5,965,377.79 357,588.99 0.84 4,131.32 MWD+IFR-AK-CAZ-SC(4) 13,699.04 89.86 152.91 7,503.03 7,432.03 -438.63 8,178.73 5,965,291.36 357,630.00 1.16 4,226.97 MWD+I FR-AK-CAZ-SC(4) 13,794.68 89.86 152.40 7,503.27 7,432.27 -523.58 8,222.66 5,965,205.55 357,672.22 0.53 4,322.60 MWD+IFR-AK-CAZ-SC(4) 13,889.71 89.89 151.37 7,503.47 7,432.47 -607.40 8,267.44 5,965,120.86 357,715.31 1.08 4,417.63 MWD+IFR-AK-CAZ-SC(4) 13,984.40 89.89 150.19 7,503.66 7,432.66 -690.04 8,313.67 5,965,037.32 357,759.86 1.25 4,512.30 MWD+IFR-AK-CAZ-SC(4) 14,080.39 89.83 149.80 7,503.89 7,432.89 -773.16 8,361.67 5,964,953.25 357,806.18 0.41 4,608.23 MWD+IFR-AK-CAZ-SC(4) 14,176.50 89.69 151.09 7,504.29 7,433.29 -856.76 8,409.08 5,964,868.72 357,851.90 1.35 4,704.30 MWD+IFR-AK-CAZ-SC(4) 14,271.15 89.89 151.19 7,504.64 7,433.64 -939.66 8,454.76 5,964,784.93 357,895.91 0.24 4,798.94 MWD+IFR-AK-CAZ-SC(4) 14,366.62 89.76 151.30 7,504.93 7,433.93 -1,023.36 8,500.69 5,964,700.34 357,940.15 0.18 4,894.40 MWD+I FR-AK-CAZ-SC(4) 14,457.83 89.76 150.44 7,505.31 7,434.31 -1,103.03 8,545.09 5,964,619.80 357,982.94 0.94 4,985.59 MWD+IFR-AK-CAZ-SC(4) 14,549.27 90.07 150.56 7,505.45 7,434.45 -1,182.61 8,590.11 5,964,539.33 358,026.36 0.36 5,077.00 MWD+I FR-AK-CAZ-SC(4) 14,641.74 90.00 151.42 7,505.39 7,434.39 -1,263.48 8,634.96 5,964,457.59 358,069.57 0.93 5,169.45 MWD+IFR-AK-CAZ-SC(4) 14,733.58 89.41 149.48 7,505.87 7,434.87 -1,343.37 8,680.25 5,964,376.82 358,113.24 2.21 5,261.25 MWD+I FR-AK-CAZ-SC(4) 14,825.32 88.54 150.17 7,507.51 7,436.51 -1,422.66 8,726.35 5,964,296.62 358,157.75 1.21 5,352.91 MWD+IFR-AK-CAZ-SC(4) 14,915.80 88.87 150.43 7,509.55 7,438.55 -1,501.24 8,771.17 5,964,217.17 358,200.98 0.46 5,443.33 MWD+I FR-AK-CAZ-SC(4) 15,007.77 88.58 149.78 7,511.60 7,440.60 -1,580.95 8,817.00 5,964,136.56 358,245.19 0.77 5,535.23 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 8:40:40AM Page 6 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,099.35 89.17 149.78 7,513.40 7,442.40 -1,660.07 8,863.08 5,964,056.54 358,289.68 0.64 5,626.72 MWD+IFR-AK-CAZ-SC(4) 15,191.66 89.62 150.95 7,514.37 7,443.37 -1,740.30 8,908.72 5,963,975.42 358,333.70 1.36 5,718.98 MWD+IFR-AK-CAZ-SC(4) 15,283.15 89.62 150.40 7,514.98 7,443.98 -1,820.06 8,953.53 5,963,894.78 358,376.89 0.60 5,810.45 MWD+IFR-AK-CAZ-SC(4) 15,375.61 89.72 150.61 7,515.51 7,444.51 -1,900.54 8,999.05 5,963,813.41 358,420.79 0.25 5,902.87 MWD+IFR-AK-CAZ-SC(4) 15,466.93 89.79 153.74 7,515.90 7,444.90 -1,981.29 9,041.67 5,963,731.83 358,461.78 3.43 5,994.18 MWD+IFR-AK-CAZ-SC(4) 15,559.67 89.79 152.33 7,516.24 7,445.24 -2,063.94 9,083.72 5,963,648.35 358,502.16 1.52 6,086.90 MWD+IFR-AK-CAZ-SC(4) 15,651.76 89.65 152.17 7,516.69 7,445.69 -2,145.44 9,126.60 5,963,566.02 358,543.39 0.23 6,178.99 MWD+IFR-AK-CAZ-SC(4) 15,742.62 89.52 152.29 7,517.35 7,446.35 -2,225.83 9,168.93 5,963,484.80 358,584.10 0.19 6,269.85 MWD+IFR-AK-CAZ-SC(4) 15,837.33 89.45 151.07 7,518.20 7,447.20 -2,309.20 9,213.86 5,963,400.55 358,627.35 1.29 6,364.55 MWD+IFR-AK-CAZ-SC(4) 15,933.70 89.79 151.82 7,518.84 7,447.84 -2,393.85 9,259.93 5,963,315.00 358,671.70 0.85 6,460.91 MWD+IFR-AK-CAZ-SC(4) 16,027.86 89.55 152.76 7,519.38 7,448.38 -2,477.21 9,303.71 5,963,230.79 358,713.80 1.03 6,555.07 MWD+IFR-AK-CAZ-SC(4) 16,123.37 89.83 152.04 7,519.90 7,448.90 -2,561.85 9,347.96 5,963,145.29 358,756.34 0.81 6,650.58 MWD+IFR-AK-CAZ-SC(4) 16,220.01 89.72 151.70 7,520.28 7,449.28 -2,647.07 9,393.52 5,963,059.17 358,800.18 0.37 6,747.21 MWD+IFR-AK-CAZ-SC(4) 16,313.91 89.76 150.82 7,520.70 7,449.70 -2,729.40 9,438.67 5,962,975.96 358,843.67 0.94 6,841.10 MWD+IFR-AK-CAZ-SC(4) 16,409.32 89.65 151.57 7,521.19 7,450.19 -2,813.00 9,484.64 5,962,891.46 358,887.95 0.79 6,936.50 MWD+IFR-AK-CAZ-SC(4) 16,505.06 89.55 150.92 7,521.86 7,450.86 -2,896.93 9,530.70 5,962,806.63 358,932.31 0.69 7,032.23 MWD+IFR-AK-CAZ-SC(4) 16,600.43 89.04 150.51 7,523.04 7,452.04 -2,980.11 9,577.34 5,962,722.54 358,977.28 0.69 7,127.57 MWD+IFR-AK-CAZ-SC(4) 16,695.74 88.73 149.56 7,524.89 7,453.89 -3,062.66 9,624.94 5,962,639.06 359,023.20 1.05 7,222.80 MWD+IFR-AK-CAZ-SC(4) 16,790.46 88.63 149.55 7,527.07 7,456.07 -3,144.30 9,672.92 5,962,556.48 359,069.54 0.11 7,317.41 MWD+IFR-AK-CAZ-SC(4) 16,886.40 88.80 148.71 7,529.22 7,458.22 -3,226.63 9,722.13 5,962,473.19 359,117.09 0.89 7,413.21 MWD+IFR-AK-CAZ-SC(4) 16,982.23 89.35 149.64 7,530.77 7,459.77 -3,308.91 9,771.23 5,962,389.95 359,164.52 1.13 7,508.91 MWD+IFR-AK-CAZ-SC(4) 17,080.35 89.93 149.61 7,531.39 7,460.39 -3,393.56 9,820.85 5,962,304.32 359,212.42 0.59 7,606.94 MWD+IFR-AK-CAZ-SC(4) 17,173.11 90.03 149.06 7,531.42 7,460.42 -3,473.35 9,868.15 5,962,223.61 359,258.12 0.60 7,699.60 MWD+IFR-AK-CAZ-SC(4) 17,269.19 90.37 149.57 7,531.09 7,460.09 -3,555.97 9,917.19 5,962,140.02 359,305.48 0.64 7,795.57 MWD+IFR-AK-CAZ-SC(4) 17,363.32 90.51 148.86 7,530.36 7,459.36 -3,636.84 9,965.36 5,962,058.22 359,352.02 0.77 7,889.59 MWD+IFR-AK-CAZ-SC(4) 17,458.41 90.07 148.62 7,529.88 7,458.88 -3,718.12 10,014.70 5,961,975.96 359,399.72 0.53 7,984.52 MWD+IFR-AK-CAZ-SC(4) 17,888.00 90.07 148.62 7,529.36 7,458.36 -4,084.87 10,238.40 5,961,604.83 359,616.00 0.00 8,413.37 NOT an Actual Survey 4 1/2"x 6-1/2" 17,900.00 90.07 148.62 7,529.34 7,458.34 -4,095.12 10,244.65 5,961,594.46 359,622.04 0.00 8,425.35 BLIND Surveys to TD Final Definitive Survey Verified and Signed-off AI!targets and/or well position objectives have been achieved. EI Yes ❑ No I have checked to the best of my ability that the following data is correct: [7] Surface Coordinates [] Declination 8 Convergence 0 Survey Tool Codes Vincent °� "a'°°'" "Ovna °r.o.-w,....ws SLB DE: Osara Ome:.15.09 155636<WOO o-sax �. ohn samuell@conoco illi AWrHbr,on�y_..� 1 A• ph' ps.corn nn.cr..4ohro_gsarnuellevonocophilhps.corn Client Representative: Da.2015D923 16,28:45-08.00 Date: 23-Sep-2015 9/24/2015 8:40:40AM Page 7 COMPASS 5000.1 Build 74 L26 3 1 5 OCT 0 8 2015 FINAL AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-05 Definitive Survey Report 23 September, 2015 NAD 83 0 Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Project Western North Slope, North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD5-05 Well Position +N/-S 0.00 usft Northing: 5,965,639.80 usfi Latitude: 70° 18'48.925 N +E/-W 0.00 usft Easting: 1,489,495.46 usfi Longitude: 151° 13'23.611 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 34.30usft',I Wellbore CD5-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/14/2015 18.06 80.83 57,473 Design CD5-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.70 0.00 0.00 152.00 Survey Program Date 9/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.40 1,006.40 CD5-05 Srvy#1 -GYD-GC-MS(CD5-05) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 10:52 1,036.18 2,233.29 CD5-05 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:3t 2,321.66 11,125.15 CD5-05 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:4C 11,219.18 17,458.41 CD5-05 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/10/2015 11:22 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.70 0.00 0.00 36.70 -34.30 0.00 0.00 5,965,639.80 1,489,495.46 0.00 0.00 UNDEFINED 115.50 0.09 323.04 115.50 44.50 0.05 -0.04 5,965,639.85 1,489,495.42 0.12 -0.06 GYD-GC-MS(1) 20"x 42" NOT an Actual Surve 170.00 0.16 323.04 170.00 99.00 0.15 -0.11 5,965,639.95 1,489,495.35 0.12 -0.18 GYD-GC-MS(1) 261.00 0.24 319.82 261.00 190.00 0.40 -0.31 5,965,640.20 1,489,495.16 0.09 -0.50 GYD-GC-MS(1) 352.00 0.53 32.27 352.00 281.00 0.90 -0.21 5,965,640.70 1,489,495.27 0.56 -0.89 GYD-GC-MS(1) 446.00 1.36 2.78 445.98 374.98 2.38 0.08 5,965,642.18 1,489,495.58 1.00 -2.06 GYD-GC-MS(1) 537.00 2.80 4.18 536.92 465.92 5.67 0.29 5,965,645.47 1,489,495.87 1.58 -4.87 GYD-GC-MS(1) 629.00 3.45 359.33 628.78 557.78 10.68 0.42 5,965,650.47 1,489,496.10 0.76 -9.23 GYD-GC-MS(1) 724.00 4.42 351.29 723.56 652.56 17.16 -0.17 5,965,656.96 1,489,495.64 1.17 -15.23 GYD-GC-MS(1) 817.00 6.30 346.15 816.15 745.15 25.66 -1.93 5,965,665.49 1,489,494.05 2.08 -23.56 GYD-GC-MS(1) 9/23/2015 3:46:24PM Page 2 COMPASS 5000.1 Build 74 SSchlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 912.00 8.23 349.75 910.38 839.38 37.41 -4.39 5,965,677.29 1,489,491.83 2.09 -35.09 GYD-GC-MS(1) 1,006.00 10.18 357.54 1,003.17 932.17 52.33 -5.94 5,965,692.24 1,489,490.57 2.46 -49.00 GYD-GC-MS(1) 1,036.18 10.17 358.79 1,032.88 961.88 57.66 -6.11 5,965,697.57 1,489,490.51 0.73 -53.78 MWD+IFR-AK-CAZ-SC(2) 1,128.82 11.64 6.28 1,123.85 1,052.85 75.13 -5.26 5,965,715.01 1,489,491.71 2.20 -68.81 MWD+IFR-AK-CAZ-SC(2) 1,222.78 12.43 11.54 1,215.74 1,144.74 94.46 -2.20 5,965,734.28 1,489,495.16 1.44 -84.44 MWD+IFR-AK-CAZ-SC(2) 1,317.28 13.55 18.16 1,307.83 1,236.83 114.95 3.28 5,965,754.65 1,489,501.05 1.97 -99.95 MWD+IFR-AK-CAZ-SC(2) 1,412.02 14.94 23.33 1,399.66 1,328.66 136.71 11.58 5,965,776.24 1,489,509.78 1.99 -115.27 MWD+IFR-AK-CAZ-SC(2) 1,506.57 17.49 28.05 1,490.44 1,419.44 160.44 23.09 5,965,799.73 1,489,521.77 3.03 -130.82 MWD+IFR-AK-CAZ-SC(2) 1,601.60 21.14 33.82 1,580.12 1,509.12 187.29 39.35 5,965,826.25 1,489,538.56 4.33 -146.90 MWD+IFR-AK-CAZ-SC(2) 1,694.39 24.51 40.27 1,665.64 1,594.64 215.89 61.11 5,965,854.41 1,489,560.90 4.52 -161.93 MWD+IFR-AK-CAZ-SC(2) 1,788.17 26.97 47.23 1,750.13 1,679.13 245.19 89.31 5,965,883.12 1,489,589.67 4.15 -174.56 MWD+IFR-AK-CAZ-SC(2) 1,882.93 29.89 50.21 1,833.46 1,762.46 274.90 123.23 5,965,912.14 1,489,624.19 3.43 -184.86 MWD+IFR-AK-CAZ-SC(2) 1,976.74 32.10 52.36 1,913.87 1,842.87 305.08 160.94 5,965,941.56 1,489,662.49 2.63 -193.82 MWD+IFR-AK-CAZ-SC(2) 2,071.48 34.09 55.30 1,993.24 1,922.24 335.58 202.71 5,965,971.21 1,489,704.86 2.70 -201.13 MWD+IFR-AK-CAZ-SC(2) 2,165.46 37.01 60.36 2,069.71 1,998.71 364.57 248.97 5,965,999.27 1,489,751.68 4.41 -205.01 MWD+IFR-AK-CAZ-SC(2) 2,233.29 37.32 61.67 2,123.77 2,052.77 384.42 284.81 5,966,018.39 1,489,787.92 1.25 -205.72 MWD+IFR-AK-CAZ-SC(2) 2,267.00 37.96 62.04 2,150.46 2,079.46 394.13 302.96 5,966,027.74 1,489,806.26 2.01 -205.77 MWD+IFR-AK-CAZ- NOT an Actual Sury 103/4"x13-1/2 2,321.66 38.99 62.63 2,193.25 2,122.25 409.92 333.08 5,966,042.91 1,489,836.69 2.01 -205.57 MWD+IFR-AK-CAZ-SC(3) 2,416.38 41.33 64.20 2,265.64 2,194.64 437.24 387.71 5,966,069.12 1,489,891.85 2.69 -204.04 MWD+IFR-AK-CAZ-SC(3) 2,511.56 43.80 66.43 2,335.74 2,264.74 464.09 446.21 5,966,094.79 1,489,950.87 3.04 -200.29 MWD+IFR-AK-CAZ-SC(3) 2,604.77 46.31 68.70 2,401.59 2,330.59 489.24 507.19 5,966,118.71 1,490,012.34 3.20 -193.86 MWD+IFR-AK-CAZ-SC(3) 2,699.24 49.00 70.31 2,465.22 2,394.22 513.66 572.59 5,966,141.81 1,490,078.21 3.11 -184.72 MWD+IFR-AK-CAZ-SC(3) 2,794.92 49.85 71.33 2,527.45 2,456.45 537.53 641.23 5,966,164.30 1,490,147.31 1.20 -173.57 MWD+IFR-AK-CAZ-SC(3) 2,888.60 49.90 71.50 2,587.82 2,516.82 560.36 709.12 5,966,185.75 1,490,215.65 0.15 -161.86 MWD+IFR-AK-CAZ-SC(3) 2,982.11 49.80 73.33 2,648.12 2,577.12 581.95 777.25 5,966,205.97 1,490,284.19 1.50 -148.94 MWD+IFR-AK-CAZ-SC(3) 3,076.74 49.97 70.94 2,709.10 2,638.10 604.15 846.12 5,966,226.78 1,490,353.49 1.94 -136.21 MWD+IFR-AK-CAZ-SC(3) 3,170.90 49.73 72.56 2,769.81 2,698.81 626.69 914.47 5,966,247.94 1,490,422.27 1.34 -124.02 MWD+IFR-AK-CAZ-SC(3) 3,265.24 49.72 71.99 2,830.80 2,759.80 648.61 983.03 5,966,268.47 1,490,491.25 0.46 -111.18 MWD+IFR-AK-CAZ-SC(3) 3,359.73 49.95 71.86 2,891.75 2,820.75 671.01 1,051.67 5,966,289.49 1,490,560.33 0.27 -98.74 MWD+IFR-AK-CAZ-SC(3) 3,453.39 49.75 71.77 2,952.14 2,881.14 693.35 1,119.69 5,966,310.46 1,490,628.77 0.23 -86.53 MWD+IFR-AK-CAZ-SC(3) 3,546.76 49.90 72.43 3,012.37 2,941.37 715.28 1,187.57 5,966,331.01 1,490,697.08 0.56 -74.02 MWD+IFR-AK-CAZ-SC(3) 3,641.22 49.75 74.33 3,073.31 3,002.31 735.92 1,256.73 5,966,350.26 1,490,766.63 1.55 -59.78 MWD+IFR-AK-CAZ-SC(3) 3,735.79 49.74 74.74 3,134.43 3,063.43 755.17 1,326.29 5,966,368.10 1,490,836.56 0.33 -44.12 MWD+IFR-AK-CAZ-SC(3) 3,829.64 49.91 74.89 3,194.97 3,123.97 773.95 1,395.49 5,966,385.49 1,490,906.12 0.22 -28.21 MWD+IFR-AK-CAZ-SC(3) 3,923.73 49.92 74.79 3,255.56 3,184.56 792.78 1,464.98 5,966,402.91 1,490,975.97 0.08 -12.22 MWD+IFR-AK-CAZ-SC(3) 4,017.51 49.68 73.43 3,316.09 3,245.09 812.39 1,533.86 5,966,421.13 1,491,045.23 1.14 2.81 MWD+IFR-AK-CAZ-SC(3) 4,112.34 49.76 72.59 3,377.40 3,306.40 833.52 1,603.05 5,966,440.87 1,491,114.82 0.68 16.63 MWD+IFR-AK-CAZ-SC(3) 4,204.12 49.61 70.91 3,436.78 3,365.78 855.44 1,669.51 5,966,461.45 1,491,181.70 1.41 28.48 MWD+IFR-AK-CAZ-SC(3) 4,298.05 49.84 68.99 3,497.51 3,426.51 880.01 1,736.82 5,966,484.66 1,491,249.49 1.58 38.39 MWD+IFR-AK-CAZ-SC(3) 4,391.45 49.53 69.34 3,557.94 3,486.94 905.34 1,803.38 5,966,508.64 1,491,316.54 0.44 47.27 MWD+IFR-AK-CAZ-SC(3) 9/23/2015 3:46:24PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,485.11 49.65 69.82 3,618.65 3,547.65 930.22 1,870.22 5,966,532.17 1,491,383.86 0.41 56.68 MWD+IFR-AK-CAZ-SC(3) 4,579.23 49.53 69.74 3,679.67 3,608.67 954.99 1,937.47 5,966,555.58 1,491,451.58 0.14 66.38 MWD+IFR-AK-CAZ-SC(3) 4,670.60 50.15 70.59 3,738.59 3,667.59 978.68 2,003.15 5,966,577.95 1,491,517.73 0.98 76.30 MWD+IFR-AK-CAZ-SC(3) 4,764.58 50.24 70.57 3,798.76 3,727.76 1,002.69 2,071.24 5,966,600.58 1,491,586.28 0.10 87.07 MWD+IFR-AK-CAZ-SC(3) 4,859.68 50.24 71.51 3,859.58 3,788.58 1,026.44 2,140.38 5,966,622.93 1,491,655.88 0.76 98.56 MWD+IFR-AK-CAZ-SC(3) 4,952.93 50.24 70.61 3,919.22 3,848.22 1,049.70 2,208.18 5,966,644.83 1,491,724.13 0.74 109.84 MWD+IFR-AK-CAZ-SC(3) 5,048.19 50.17 70.77 3,980.19 3,909.19 1,073.91 2,277.26 5,966,667.64 1,491,793.67 0.15 120.90 MWD+I FR-AK-CAZ-SC(3) 5,141.18 50.36 71.07 4,039.64 3,968.64 1,097.28 2,344.84 5,966,689.65 1,491,861.70 0.32 131.99 MWD+I FR-AK-CAZ-S C(3) 5,235.58 50.25 71.96 4,099.93 4,028.93 1,120.31 2,413.73 5,966,711.29 1,491,931.04 0.73 144.00 MWD+I FR-AK-CAZ-SC(3) 5,330.57 50.20 72.22 4,160.70 4,089.70 1,142.76 2,483.19 5,966,732.34 1,492,000.94 0.22 156.79 MWD+I FR-AK-CAZ-SC(3) 5,424.99 50.21 72.10 4,221.13 4,150.13 1,164.99 2,552.25 5,966,753.17 1,492,070.42 0.10 169.59 MWD+IFR-AK-CAZ-SC(3) 5,518.94 50.38 72.00 4,281.15 4,210.15 1,187.26 2,621.01 5,966,774.06 1,492,139.61 0.20 182.20 MWD+IFR-AK-CAZ-SC(3) 5,612.48 50.32 71.00 4,340.84 4,269.84 1,210.12 2,689.31 5,966,795.53 1,492,208.35 0.83 194.09 MWD+IFR-AK-CAZ-SC(3) 5,706.88 50.06 72.28 4,401.28 4,330.28 1,232.96 2,758.13 5,966,816.98 1,492,277.61 1.08 206.23 MWD+IFR-AK-CAZ-SC(3) 5,800.90 50.22 73.11 4,461.54 4,390.54 1,254.43 2,827.04 5,966,837.06 1,492,346.93 0.70 219.62 MWD+I FR-AK-CAZ-SC(3) 5,894.93 50.54 74.11 4,521.50 4,450.50 1,274.86 2,896.52 5,966,856.09 1,492,416.81 0.89 234.20 MWD+IFR-AK-CAZ-SC(3) 5,988.68 50.75 72.19 4,580.96 4,509.96 1,295.87 2,965.89 5,966,875.70 1,492,486.58 1.60 248.21 MWD+IFR-AK-CAZ-SC(3) 6,083.86 50.87 72.59 4,641.10 4,570.10 1,318.19 3,036.21 5,966,896.60 1,492,557.32 0.35 261.52 MWD+I FR-AK-CAZ-SC(3) 6,177.29 50.83 72.79 4,700.09 4,629.09 1,339.75 3,105.38 5,966,916.76 1,492,626.91 0.17 274.96 MWD+I FR-AK-CAZ-SC(3) 6,271.84 50.23 72.22 4,760.19 4,689.19 1,361.69 3,174.99 5,966,937.30 1,492,696.94 0.79 288.27 MWD+IFR-AK-CAZ-SC(3) 6,366.56 50.36 71.43 4,820.70 4,749.70 1,384.42 3,244.23 5,966,958.63 1,492,766.62 0.66 300.70 MWD+IFR-AK-CAZ-SC(3) 6,461.05 50.13 69.81 4,881.13 4,810.13 1,408.52 3,312.75 5,966,981.35 1,492,835.60 1.34 311.59 MWD+IFR-AK-CAZ-SC(3) 6,554.50 50.13 70.54 4,941.04 4,870.04 1,432.85 3,380.22 5,967,004.31 1,492,903.55 0.60 321.79 MWD+IFR-AK-CAZ-SC(3) 6,650.30 50.14 71.55 5,002.44 4,931.44 1,456.73 3,449.76 5,967,026.79 1,492,973.55 0.81 333.35 MWD+IFR-AK-CAZ-SC(3) 6,744.34 50.21 72.02 5,062.67 4,991.67 1,479.31 3,518.37 5,967,047.98 1,493,042.59 0.39 345.62 MWD+I FR-AK-CAZ-SC(3) 6,838.05 50.10 71.80 5,122.71 5,051.71 1,501.65 3,586.76 5,967,068.94 1,493,111.41 0.22 358.00 MWD+I FR-AK-CAZ-SC(3) 6,933.37 50.18 72.15 5,183.81 5,112.81 1,524.29 3,656.34 5,967,090.18 1,493,181.42 0.29 370.68 MWD+IFR-AK-CAZ-SC(3) 7,026.40 50.20 71.27 5,243.37 5,172.37 1,546.72 3,724.19 5,967,111.23 1,493,249.71 0.73 382.73 MWD+IFR-AK-CAZ-SC(3) 7,121.17 50.30 70.01 5,303.97 5,232.97 1,570.87 3,792.93 5,967,134.00 1,493,318.91 1.03 393.68 MWD+I FR-AK-CAZ-SC(3) 7,214.11 50.20 68.99 5,363.40 5,292.40 1,595.89 3,859.86 5,967,157.67 1,493,386.33 0.85 403.00 MWD+IFR-AK-CAZ-SC(3) 7,310.65 50.15 68.43 5,425.23 5,354.23 1,622.81 3,928.94 5,967,183.20 1,493,455.93 0.45 411.67 MWD+I FR-AK-CAZ-SC(3) 7,404.66 50.05 69.36 5,485.53 5,414.53 1,648.78 3,996.22 5,967,207.81 1,493,523.72 0.77 420.32 MWD+IFR-AK-CAZ-SC(3) 7,499.39 50.09 70.39 5,546.34 5,475.34 1,673.78 4,064.43 5,967,231.42 1,493,592.41 0.83 430.28 MWD+IFR-AK-CAZ-SC(3) 7,592.46 50.37 70.70 5,605.87 5,534.87 1,697.60 4,131.88 5,967,253.88 1,493,660.32 0.40 440.91 MWD+IFR-AK-CAZ-SC(3) 7,687.75 50.33 71.48 5,666.68 5,595.68 1,721.38 4,201.29 5,967,276.26 1,493,730.19 0.63 452.50 MWD+I FR-AK-CAZ-SC(3) 7,781.73 50.67 71.21 5,726.46 5,655.46 1,744.57 4,269.99 5,967,298.07 1,493,799.34 0.42 464.27 MWD+IFR-AK-CAZ-SC(3) 7,876.29 50.48 70.96 5,786.51 5,715.51 1,768.25 4,339.09 5,967,320.35 1,493,868.90 0.29 475.81 MWD+IFR-AK-CAZ-SC(3) 7,970.75 50.41 70.55 5,846.66 5,775.66 1,792.26 4,407.85 5,967,342.97 1,493,938.12 0.34 486.89 MWD+IFR-AK-CAZ-SC(3) 8,065.19 51.14 71.43 5,906.38 5,835.38 1,816.08 4,477.02 5,967,365.40 1,494,007.75 1.06 498.33 MWD+IFR-AK-CAZ-SC(3) 8,158.89 51.02 72.20 5,965.25 5,894.25 1,838.84 4,546.28 5,967,386.75 1,494,077.44 0.65 510.75 MWD+IFR-AK-CAZ-SC(3) 9/23/2015 3:46:24PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 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) (°/100') (ft) Survey Tool Name 8,252.93 51.07 72.38 6,024.37 5,953.37 1,861.08 4,615.94 5,967,407.59 1,494,147.54 0.16 523.82 MWD+IFR-AK-CAZ-SC(3) 8,347.58 51.09 73.00 6,083.84 6,012.84 1,882.99 4,686.25 5,967,428.08 1,494,218.26 0.51 537.48 MWD+IFR-AK-CAZ-SC(3) 8,440.63 50.54 74.04 6,142.63 6,071.63 1,903.45 4,755.41 5,967,447.15 1,494,287.81 1.05 551.88 MWD+IFR-AK-CAZ-SC(3) 8,535.48 50.09 74.21 6,203.20 6,132.20 1,923.42 4,825.62 5,967,465.70 1,494,358.40 0.49 567.21 MWD+IFR-AK-CAZ-SC(3) 8,630.19 50.11 74.83 6,263.95 6,192.95 1,942.81 4,895.64 5,967,483.68 1,494,428.79 0.50 582.96 MWD+IFR-AK-CAZ-SC(3) 8,725.00 49.89 74.44 6,324.89 6,253.89 1,962.06 4,965.67 5,967,501.51 1,494,499.19 0.39 598.85 MWD+IFR-AK-CAZ-SC(3) 8,819.59 49.87 75.44 6,385.84 6,314.84 1,980.85 5,035.52 5,967,518.89 1,494,569.40 0.81 615.04 MWD+IFR-AK-CAZ-SC(3) 8,914.57 50.69 76.23 6,446.54 6,375.54 1,998.73 5,106.35 5,967,535.34 1,494,640.57 1.07 632.52 MWD+IFR-AK-CAZ-SC(3) 9,008.49 50.68 74.31 6,506.05 6,435.05 2,017.20 5,176.62 5,967,552.40 1,494,711.20 1.58 649.19 MWD+IFR-AK-CAZ-SC(3) 9,102.83 50.79 71.58 6,565.77 6,494.77 2,038.62 5,246.44 5,967,572.41 1,494,781.42 2.24 663.06 MWD+IFR-AK-CAZ-SC(3) 9,198.29 50.80 68.86 6,626.11 6,555.11 2,063.65 5,316.03 5,967,596.03 1,494,851.50 2.21 673.63 MWD+IFR-AK-CAZ-SC(3) 9,291.98 50.55 68.58 6,685.49 6,614.49 2,089.95 5,383.57 5,967,620.97 1,494,919.55 0.35 682.11 MWD+IFR-AK-CAZ-SC(3) 9,386.31 50.39 70.25 6,745.53 6,674.53 2,115.53 5,451.67 5,967,645.17 1,494,988.15 1.38 691.50 MWD+IFR-AK-CAZ-SC(3) 9,480.79 51.05 74.42 6,805.36 6,734.36 2,137.70 5,521.33 5,967,665.94 1,495,058.23 3.49 704.63 MWD+IFR-AK-CAZ-SC(3) 9,528.99 51.04 78.17 6,835.67 6,764.67 2,146.58 5,557.73 5,967,674.08 1,495,094.80 6.05 713.88 MWD+IFR-AK-CAZ-SC(3) 9,574.71 51.36 80.61 6,864.32 6,793.32 2,153.14 5,592.75 5,967,679.93 1,495,129.94 4.22 724.53 MWD+IFR-AK-CAZ-SC(3) 9,620.96 51.95 82.82 6,893.02 6,822.02 2,158.36 5,628.64 5,967,684.43 1,495,165.93 3.96 736.77 MWD+IFR-AK-CAZ-SC(3) 9,669.50 53.25 84.87 6,922.50 6,851.50 2,162.49 5,666.98 5,967,687.79 1,495,204.34 4.29 751.12 MWD+IFR-AK-CAZ-SC(3) 9,763.43 54.60 89.13 6,977.82 6,906.82 2,166.44 5,742.76 5,967,690.21 1,495,280.18 3.94 783.21 MWD+IFR-AK-CAZ-SC(3) 9,856.52 54.68 94.02 7,031.72 6,960.72 2,164.35 5,818.61 5,967,686.60 1,495,355.97 4.28 820.67 MWD+IFR-AK-CAZ-SC(3) 9,951.28 55.34 97.77 7,086.07 7,015.07 2,156.37 5,895.81 5,967,677.07 1,495,432.98 3.32 863.95 MWD+IFR-AK-CAZ-SC(3) 10,046.00 56.00 100.67 7,139.50 7,068.50 2,143.83 5,973.01 5,967,662.99 1,495,509.91 2.62 911.27 MWD+IFR-AK-CAZ-SC(3) 10,140.61 57.96 103.58 7,191.06 7,120.06 2,127.15 6,050.54 5,967,644.75 1,495,587.09 3.31 962.40 MWD+IFR-AK-CAZ-SC(3) 10,235.45 60.41 106.52 7,239.64 7,168.64 2,105.98 6,129.17 5,967,622.01 1,495,665.27 3.71 1,018.00 MWD+IFR-AK-CAZ-SC(3) 10,329.65 62.63 109.47 7,284.57 7,213.57 2,080.38 6,207.90 5,967,594.84 1,495,743.46 3.62 1,077.56 MWD+IFR-AK-CAZ-SC(3) 10,422.01 66.34 111.84 7,324.35 7,253.35 2,050.97 6,285.86 5,967,563.86 1,495,820.81 4.64 1,140.14 MWD+IFR-AK-CAZ-SC(3) 10,516.37 69.24 113.95 7,360.02 7,289.02 2,016.97 6,366.32 5,967,528.25 1,495,900.56 3.71 1,207.93 MWD+IFR-AK-CAZ-SC(3) 10,610.31 73.35 114.97 7,390.14 7,319.14 1,980.13 6,447.29 5,967,489.79 1,495,980.77 4.49 1,278.47 MWD+IFR-AK-CAZ-SC(3) 10,703.60 77.19 115.44 7,413.85 7,342.85 1,941.71 6,528.91 5,967,449.75 1,496,061.59 4.14 1,350.71 MWD+IFR-AK-CAZ-SC(3) 10,798.65 79.87 116.66 7,432.75 7,361.75 1,900.80 6,612.58 5,967,407.17 1,496,144.42 3.09 1,426.11 MWD+IFR-AK-CAZ-SC(3) 10,892.12 81.12 118.00 7,448.19 7,377.19 1,858.48 6,694.48 5,967,363.21 1,496,225.44 1.95 1,501.93 MWD+IFR-AK-CAZ-SC(3) 10,986.96 82.59 119.17 7,461.63 7,390.63 1,813.56 6,776.91 5,967,316.65 1,496,306.95 1.97 1,580.29 MWD+IFR-AK-CAZ-SC(3) 11,081.16 84.51 120.81 7,472.21 7,401.21 1,766.77 6,857.97 5,967,268.24 1,496,387.05 2.67 1,659.66 MWD+IFR-AK-CAZ-SC(3) 11,125.15 84.75 121.35 7,476.33 7,405.33 1,744.16 6,895.48 5,967,244.89 1,496,424.10 1.34 1,697.23 MWD+IFR-AK-CAZ-SC(3) 11,176.80 86.42 122.77 7,480.30 7,409.30 1,716.83 6,939.12 5,967,216.68 1,496,467.17 4.24 1,741.85 MWD+IFR-AK-CAZ- 7-5/8"x 9-7/8" NOT an Actual Sun/ 11,219.18 87.79 123.93 7,482.44 7,411.44 1,693.56 6,974.48 5,967,192.71 1,496,502.05 4.24 1,778.99 MWD+IFR-AK-CAZ-SC(4) 11,315.42 88.69 126.50 7,485.40 7,414.40 1,638.10 7,053.06 5,967,135.68 1,496,579.50 2.83 1,864.86 MWD+IFR-AK-CAZ-SC(4) 11,411.53 89.55 129.95 7,486.88 7,415.88 1,578.64 7,128.54 5,967,074.73 1,496,653.76 3.70 1,952.79 MWD+IFR-AK-CAZ-SC(4) 11,459.09 89.71 132.83 7,487.18 7,416.18 1,547.20 7,164.22 5,967,042.58 1,496,688.80 6.06 1,997.30 MWD+IFR-AK-CAZ-SC(4) 11,504.67 90.34 136.47 7,487.16 7,416.16 1,515.18 7,196.64 5,967,009.91 1,496,720.57 8.10 2,040.80 MWD+IFR-AK-CAZ-SC(4) 9/23/2015 3:46:24PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,554.31 89.34 139.42 7,487.30 7,416.30 1,478.32 7,229.89 5,966,972.40 1,496,753.06 6.27 2,088.94 MWD+IFR-AK-CAZ-SC(4) 11,600.60 90.23 141.69 7,487.48 7,416.48 1,442.58 7,259.29 5,966,936.07 1,496,781.74 5.27 2,134.31 MWD+IFR-AK-CAZ-SC(4) 11,696.04 90.03 143.62 7,487.26 7,416.26 1,366.71 7,317.19 5,966,859.06 1,496,838.09 2.03 2,228.48 MWD+IFR-AK-CAZ-SC(4) 11,791.92 89.89 146.70 7,487.33 7,416.33 1,288.02 7,371.95 5,966,779.30 1,496,891.27 3.22 2,323.67 MWD+I FR-AK-CAZ-SC(4) 11,887.57 90.27 150.03 7,487.19 7,416.19 1,206.60 7,422.12 5,966,696.89 1,496,939.78 3.50 2,419.11 MWD+I FR-AK-CAZ-SC(4) 11,982.10 90.00 154.27 7,486.97 7,415.97 1,123.04 7,466.27 5,966,612.46 1,496,982.24 4.49 2,513.62 MWD+I FR-AK-CAZ-SC(4) 12,077.59 90.37 155.68 7,486.66 7,415.66 1,036.51 7,506.66 5,966,525.15 1,497,020.88 1.53 2,608.98 MWD+IFR-AK-CAZ-SC(4) 12,173.12 90.56 154.55 7,485.89 7,414.89 949.86 7,546.86 5,966,437.71 1,497,059.32 1.20 2,704.36 MWD+IFR-AK-CAZ-SC(4) 12,268.08 89.71 154.72 7,485.66 7,414.66 864.05 7,587.53 5,966,351.11 1,497,098.27 0.91 2,799.22 MWD+IFR-AK-CAZ-SC(4) 12,363.92 89.86 154.69 7,486.02 7,415.02 777.40 7,628.48 5,966,263.66 1,497,137.46 0.16 2,894.95 MWD+IFR-AK-CAZ-SC(4) 12,459.34 89.41 154.35 7,486.63 7,415.63 691.27 7,669.53 5,966,176.72 1,497,176.77 0.59 2,990.28 MWD+IFR-AK-CAZ-SC(4) 12,554.74 89.11 155.88 7,487.86 7,416.86 604.73 7,709.67 5,966,089.41 1,497,215.16 1.63 3,085.52 MWD+IFR-AK-CAZ-SC(4) 12,650.39 88.93 155.18 7,489.50 7,418.50 517.69 7,749.29 5,966,001.59 1,497,253.01 0.76 3,180.98 MWD+IFR-AK-CAZ-SC(4) 12,745.68 89.45 156.75 7,490.85 7,419.85 430.67 7,788.09 5,965,913.82 1,497,290.06 1.74 3,276.03 MWD+IFR-AK-CAZ-SC(4) 12,840.55 89.77 156.28 7,491.49 7,420.49 343.66 7,825.90 5,965,826.07 1,497,326.10 0.60 3,370.60 MWD+IFR-AK-CAZ-SC(4) 12,936.09 89.13 157.80 7,492.41 7,421.41 255.70 7,863.16 5,965,737.38 1,497,361.59 1.73 3,465.76 MWD+IFR-AK-CAZ-SC(4) 13,031.28 89.38 156.49 7,493.65 7,422.65 167.99 7,900.13 5,965,648.96 1,497,396.79 1.40 3,560.56 MWD+IFR-AK-CAZ-SC(4) 13,126.49 89.45 156.43 7,494.62 7,423.62 80.71 7,938.15 5,965,560.94 1,497,433.04 0.10 3,655.48 MWD+IFR-AK-CAZ-SC(4) 13,221.98 88.93 156.35 7,495.97 7,424.97 -6.78 7,976.40 5,965,472.70 1,497,469.52 0.55 3,750.68 MWD+IFR-AK-CAZ-SC(4) 13,317.60 88.83 156.23 7,497.84 7,426.84 -94.31 8,014.84 5,965,384.42 1,497,506.19 0.16 3,846.01 MWD+IFR-AK-CAZ-SC(4) 13,412.85 88.80 155.70 7,499.81 7,428.81 -181.28 8,053.62 5,965,296.69 1,497,543.22 0.56 3,941.01 MWD+IFR-AK-CAZ-SC(4) 13,508.02 88.97 153.90 7,501.66 7,430.66 -267.38 8,094.14 5,965,209.81 1,497,581.99 1.90 4,036.05 MWD+I FR-AK-CAZ-SC(4) 13,603.36 89.76 154.02 7,502.72 7,431.72 -353.03 8,135.99 5,965,123.34 1,497,622.10 0.84 4,131.32 MWD+IFR-AK-CAZ-SC(4) 13,699.04 89.86 152.91 7,503.03 7,432.03 -438.63 8,178.73 5,965,036.90 1,497,663.12 1.16 4,226.97 MWD+IFR-AK-CAZ-SC(4) 13,794.68 89.86 152.40 7,503.27 7,432.27 -523.58 8,222.66 5,964,951.09 1,497,705.33 0.53 4,322.60 MWD+IFR-AK-CAZ-SC(4) 13,889.71 89.89 151.37 7,503.47 7,432.47 -607.40 8,267.44 5,964,866.40 1,497,748.41 1.08 4,417.63 MWD+IFR-AK-CAZ-SC(4) 13,984.40 89.89 150.19 7,503.66 7,432.66 -690.04 8,313.67 5,964,782.85 1,497,792.96 1.25 4,512.30 MWD+IFR-AK-CAZ-SC(4) 14,080.39 89.83 149.80 7,503.89 7,432.89 -773.16 8,361.67 5,964,698.79 1,497,839.28 0.41 4,608.23 MWD+IFR-AK-CAZ-SC(4) 14,176.50 89.69 151.09 7,504.29 7,433.29 -856.76 8,409.08 5,964,614.25 1,497,884.99 1.35 4,704.30 MWD+IFR-AK-CAZ-SC(4) 14,271.15 89.89 151.19 7,504.64 7,433.64 -939.66 8,454.76 5,964,530.47 1,497,929.00 0.24 4,798.94 MWD+I FR-AK-CAZ-SC(4) 14,366.62 89.76 151.30 7,504.93 7,433.93 -1,023.36 8,500.69 5,964,445.87 1,497,973.23 0.18 4,894.40 MWD+I FR-AK-CAZ-SC(4) 14,457.83 89.76 150.44 7,505.31 7,434.31 -1,103.03 8,545.09 5,964,365.33 1,498,016.02 0.94 4,985.59 MWD+I FR-AK-CAZ-SC(4) 14,549.27 90.07 150.56 7,505.45 7,434.45 -1,182.61 8,590.11 5,964,284.86 1,498,059.43 0.36 5,077.00 MWD+I FR-AK-CAZ-SC(4) 14,641.74 90.00 151.42 7,505.39 7,434.39 -1,263.48 8,634.96 5,964,203.11 1,498,102.64 0.93 5,169.45 MWD+IFR-AK-CAZ-SC(4) 14,733.58 89.41 149.48 7,505.87 7,434.87 -1,343.37 8,680.25 5,964,122.33 1,498,146.31 2.21 5,261.25 MWD+IFR-AK-CAZ-SC(4) 14,825.32 88.54 150.17 7,507.51 7,436.51 -1,422.66 8,726.35 5,964,042.14 1,498,190.81 1.21 5,352.91 MWD+I FR-AK-CAZ-SC(4) 14,915.80 88.87 150.43 7,509.55 7,438.55 -1,501.24 8,771.17 5,963,962.68 1,498,234.03 0.46 5,443.33 MWD+I FR-AK-CAZ-SC(4) 15,007.77 88.58 149.78 7,511.60 7,440.60 -1,580.95 8,817.00 5,963,882.07 1,498,278.25 0.77 5,535.23 MWD+IFR-AK-CAZ-SC(4) 15,099.35 89.17 149.78 7,513.40 7,442.40 -1,660.07 8,863.08 5,963,802.05 1,498,322.73 0.64 5,626.72 MWD+IFR-AK-CAZ-SC(4) 15,191.66 89.62 150.95 7,514.37 7,443.37 -1,740.30 8,908.72 5,963,720.92 1,498,366.75 1.36 5,718.98 MWD+IFR-AK-CAZ-SC(4) 9/23/2015 3:46:24PM Page 6 COMPASS 5000.1 Build 74 . i Schlumberger S Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 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) (°/100') (ft) Survey Tool Name 15,283.15 89.62 150.40 7,514.98 7,443.98 -1,820.06 8,953.53 5,963,640.28 1,498,409.94 0.60 5,810.45 MWD+IFR-AK-CAZ-SC(4) 15,375.61 89.72 150.61 7,515.51 7,444.51 -1,900.54 8,999.05 5,963,558.91 1,498,453.83 0.25 5,902.87 MWD+IFR-AK-CAZ-SC(4) 15,466.93 89.79 153.74 7,515.90 7,444.90 -1,981.29 9,041.67 5,963,477.33 1,498,494.81 3.43 5,994.18 MWD+IFR-AK-CAZ-SC(4) 15,559.67 89.79 152.33 7,516.24 7,445.24 -2,063.94 9,083.72 5,963,393.85 1,498,535.19 1.52 6,086.90 MWD+IFR-AK-CAZ-SC(4) 15,651.76 89.65 152.17 7,516.69 7,445.69 -2,145.44 9,126.60 5,963,311.51 1,498,576.42 0.23 6,178.99 MWD+IFR-AK-CAZ-SC(4) 15,742.62 89.52 152.29 7,517.35 7,446.35 -2,225.83 9,168.93 5,963,230.29 1,498,617.13 0.19 6,269.85 MWD+IFR-AK-CAZ-SC(4) 15,837.33 89.45 151.07 7,518.20 7,447.20 -2,309.20 9,213.86 5,963,146.04 1,498,660.36 1.29 6,364.55 MWD+IFR-AK-CAZ-SC(4) 15,933.70 89.79 151.82 7,518.84 7,447.84 -2,393.85 9,259.93 5,963,060.50 1,498,704.71 0.85 6,460.91 MWD+IFR-AK-CAZ-SC(4) 16,027.86 89.55 152.76 7,519.38 7,448.38 -2,477.21 9,303.71 5,962,976.28 1,498,746.81 1.03 6,555.07 MWD+IFR-AK-CAZ-SC(4) 16,123.37 89.83 152.04 7,519.90 7,448.90 -2,561.85 9,347.96 5,962,890.77 1,498,789.34 0.81 6,650.58 MWD+IFR-AK-CAZ-SC(4) 16,220.01 89.72 151.70 7,520.28 7,449.28 -2,647.07 9,393.52 5,962,804.66 1,498,833.18 0.37 6,747.21 MWD+IFR-AK-CAZ-SC(4) 16,313.91 89.76 150.82 7,520.70 7,449.70 -2,729.40 9,438.67 5,962,721.44 1,498,876.66 0.94 6,841.10 MWD+IFR-AK-CAZ-SC(4) 16,409.32 89.65 151.57 7,521.19 7,450.19 -2,813.00 9,484.64 5,962,636.94 1,498,920.94 0.79 6,936.50 MWD+IFR-AK-CAZ-SC(4) 16,505.06 89.55 150.92 7,521.86 7,450.86 -2,896.93 9,530.70 5,962,552.11 1,498,965.30 0.69 7,032.23 MWD+IFR-AK-CAZ-SC(4) 16,600.43 89.04 150.51 7,523.04 7,452.04 -2,980.11 9,577.34 5,962,468.02 1,499,010.26 0.69 7,127.57 MWD+IFR-AK-CAZ-SC(4) 16,695.74 88.73 149.56 7,524.89 7,453.89 -3,062.66 9,624.94 5,962,384.53 1,499,056.18 1.05 7,222.80 MWD+IFR-AK-CAZ-SC(4) 16,790.46 88.63 149.55 7,527.07 7,456.07 -3,144.30 9,672.92 5,962,301.95 1,499,102.51 0.11 7,317.41 MWD+IFR-AK-CAZ-SC(4) 16,886.40 88.80 148.71 7,529.22 7,458.22 -3,226.63 9,722.13 5,962,218.66 1,499,150.06 0.89 7,413.21 MWD+IFR-AK-CAZ-SC(4) 16,982.23 89.35 149.64 7,530.77 7,459.77 -3,308.91 9,771.23 5,962,135.41 1,499,197.49 1.13 7,508.91 MWD+IFR-AK-CAZ-SC(4) 17,080.35 89.93 149.61 7,531.39 7,460.39 -3,393.56 9,820.85 5,962,049.79 1,499,245.39 0.59 7,606.94 MWD+IFR-AK-CAZ-SC(4) 17,173.11 90.03 149.06 7,531.42 7,460.42 -3,473.35 9,868.15 5,961,969.07 1,499,291.08 0.60 7,699.60 MWD+IFR-AK-CAZ-SC(4) 17,269.19 90.37 149.57 7,531.09 7,460.09 -3,555.97 9,917.19 5,961,885.48 1,499,338.43 0.64 7,795.57 MWD+IFR-AK-CAZ-SC(4) 17,363.32 90.51 148.86 7,530.36 7,459.36 -3,636.84 9,965.36 5,961,803.67 1,499,384.97 0.77 7,889.59 MWD+IFR-AK-CAZ-SC(4) 17,458.41 90.07 148.62 7,529.88 7,458.88 -3,718.12 10,014.70 5,961,721.42 1,499,432.67 0.53 7,984.52 MWD+IFR-AK-CAZ-SC(4) 17,888.00 90.07 148.62 7,529.36 7,458.36 -4,084.87 10,238.40 5,961,350.27 1,499,648.93 0.00 8,413.37 41/2"x 6-1/2" NOTan Actual Survey 17,900.00 90.07 148.62 7,529.34 7,458.34 -4,095.12 10,244.65 5,961,339.90 1,499,654.97 0.00 8,425.35 BLIND Surveys o I L) Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. El Yes ❑ No I have checked to the best of my ability that the following data is correct: 2 Surface Coordinates [� Declination & Convergence ❑ Survey Tool Codes Digital*w�wv.� , .o. Vincent PNrr-, re Ow. StlNtnrbetger,eu-XH ntaver. SLB DE: Osara ;°5 -,O. DigdatHigroed M john.gsamuea®conxophapasom john.g.samuell@conocophillips.com ON:a.;ohn.gsanweMpmnocophiAgs.com Client Representative: Date:2015.0913162845-0ero0 Date: 23-Sep-2015 9/23/2015 3:46:24PM Page 7 COMPASS 5000.1 Build 74 REC WED • STATE OF ALASKA • OCT 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND4ACACC 1a.Well Status: Oil E, Gas❑ SPLUG 0 Other ❑ Abandoned ❑ Suspended❑ 11 b.Well Class: 20AAC 25.105 20AAC 25.110 Development E✓ ' Exploratory 111 GINJ Li 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.: >9/8/2015 •215-073 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 , 8/13/2015 . 50-103-20712-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 316'FNL,2517'FEL, Sec. 18,T11 N, R4E, UM .9/2/2015 •CRU CD5-05 Top of Productive Interval: 9. KB(ft above MSL): 71' 17. Field/Pool(s): 3849'FNL, 902'FEL, Sec. 8,T11 N, R4E, UM GL(ft above MSL): 34.3' Colville River Unit/Alpine Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4419'FNL,2848'FEL,Sec. 16,T11 N, R4E, UM 17888'MD/7529'TVD ASRC NPR4,ASRC NPR2, 387208' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 349462 y- 5965894 Zone- 4 •17900'MD/7529'TVD 932128, 932671,932193 TPI: x- 356383 y- 5967505 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 359622 y- 5961594 Zone- 4 nipple @ 537'MD/537'TVD 1314'MD/1305'TVD 5. Directional or Inclination Survey: Yes : L✓ (attached) No 0 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. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6# B 36.5' 115.5 36.5' 115.5' 42" 5.5 sx 10.75" 45.5# L-80 35' 2267' 35' 2150' 13.5" 1250 sx DeepCRETE,285 sx Class G 7.625" 29.7/39 L80/TN11C 35' 11177' 35' 7480' 9.875" 93 bbls Class G,91 bbls Class G 4.5" 12.6# L-80 10997' 17888' 7463' 7529' 6.5" uncemented liner with frac sleeves 24. Open to production or injection? Yes E No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 11013' 10997'MD/7463'TVD frac ports from 11721'-17129'MD and 7487'-7531'TVD & 10537'MD/7367'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 /qj j�(� ' Per 20 AAC 25.283(i)(2)attach electronic and printed information �A�� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED /V a 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 -O. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate -4 Form 10-407 Revised 5/2015 1/77--- . 9/2 3,/,5 CONTINUWN�GE 2 RBDMS j OCT o9- ?015 Submit ORIGINIAL on 28.CORE DATA Conventional CO: Yes ❑ No ❑ Sidewall Cores:Os ❑ 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 TVD Well tested? Yes ❑ No ❑l Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1314' 1305' Attach separate pages to this form, if needed, and submit detailed test information, including reports,per 20 AAC 25.071. C-30 2495' 2324' Alpine A Alpine C 10664' 7405' HRZ 9920' 7068' Kalubik 10077' 7157' Kuparuk C 10294' 7268' Lower Kalubik 10148' 7195' Miluveach 10303' 7272' b4 a# ,,( 4-o, 'hvti—C nta.-lk.-s.M.6- "1-3 Formation at total depth: Alpine A 31. List of Attachments: Summary of Operations,definitive survey,schematic,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. Contact: Will Earhart @ 265-1077 Email: William.C.Earhart@cop.com Printed Name: Graham L.Alvord Title: Alaska Drilling Manager Signature: 1,-> Phone: 265-6120 Date: (f)(21a INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: 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 TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • • Top Actual MD Actual TVD Actual TVDSSI C30 2494.73 2323.34 -2252.74 K3 4733.96 3779.15 -3708.55 K2 5099.98 4013.3 -3942.7 Albian 97 5756.88 4433.32 -4362.72 Albian 96 7749.42 5705.9 -5635.3 HRZ (FCS) 9704.59 6943.17 -6872.57 Kalubik (Base HRZ) 10077.45 7156.63 -7086.03 Kuparuk C 10294.04 7267.58 -7196.98 LCU/ Miluveach 10303.14 7271.92 -7201.32 Alpine C 10664.2 7403.84 -7333.24 UJU 10665.64 7404.2 -7333.6 Alpine A 11114.99 7475.38 -7404.78 WNS PROD CD5-05 Conoc PhiIIi ps ,.,; Well Attributes • ie,&*D 7i Alaska(NC 5 rK Wellbore API/UWI Field Name Wellbore Status I(°) MD(ftKB) Act Btm(ftKB) , 501032071200 ALPINE PROD 90.55 12,173.12 17,900.0 -•• Comment 625(ppm) Date Annotation End Date KB-Grd(ft) 1Rig Release Date CD5-05,9/23/20152:43:19 PM SSSV:NIPPLE Last WO: 36.501 9/8/2015 VeNcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- --- - -- -------Last Tag: Rev Reason:NEW WELL smsmith 9/23/2015 HANGER,308�� 1 easing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..,WI/Len(1..Grade Top Thread „, CONDUCTOR 20 19.000 36.5 115.5 115.5 78.60 B Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sel Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 35.2 2,267.0 2,150.5 45.50 L-80 Hyd 563 CONDUCTOR;36.5-115.5- N, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 352 11,176.8 7,480.3 29.70 L80 BTCM lE Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread lE LINER 4 1/2 3.958 10,997.3 17,888.0 7,529.4 12 60 L-80 IBT-M le Liner Details , NIPPLE 537.3 Nominal ID Top(ftKB) Top(TVD)((tKB) Top Incl(°) Item Des Com (in) 10,997.3 7,462.9 62.80 PACKER BAKER HRD-3 ZXP LINER TOP PACKER 5.270 11,018.6 7,465.5 83.23 NIPPLE BAKER RS NIPPLE 4.050 11,020.9 7,465.8 83.28 HANGER BAKER DG FLEXLOCK LINER HANGER 4.170 11,030.8 7,466.9 83.48 XO Reducing Cross over,5"BTC-M x 4-1/2"IBT-M,L-80 3.880 11,651.6 7,487.4 90.11 SLEEVE CAMCO SLIDING SLEEVE W/D PROFILE(OPEN 2750 SURFACE;352-2,26]0 ° DOWN) 11,721.4 7,487.3 89.99 FRAC PORT FRAC PORT#9,BALL 2.063"(2.05"ID) 3.900 GAS LIFT;4,196.5 I 12,351.4 7,486.0 89.84 FRAC PORT FRAC PORT#8,BALL 2.000"(1.954"ID) 3.900 13,018.1 7,493.6 89.35 FRAC PORT FRAC PORT#7,BALL 1.938"(1.890"ID) 3.900 13,691.4 7,503.1 89.85 FRAC PORT FRAC PORT#6,BALL 1.875"(1.83"ID) 3.900 al 14,359.3 7,505.0 89,77 FRAC PORT FRAC PORT#5,BALL 1.813"(1.77"ID) 3.900 GAS LIFT;7soas 15,027.4 7,512.1 88.71 FRAC PORT FRAC PORT#4,BALL 1.75"(1.71"ID) 3.900 15,739.5 7,517.3 89.52 FRAC PORT -FRAC PORT#3,BALL 1.688"(1.64"ID) 3.900 16,410.8 7,521.2 89.65 FRAC PORT FRAC PORT#2,BALL 1.625"(1.59"ID) 3.900 GAS LIFT;10417.4 17,126.4 7,531.4 89.98 FRAC PORT FRAC PORT#1,BALL 1.563"(1.55"ID) 3.900 Tubing Strings • Tubing Description String Ma.,.ID(in) Top(BOB) Set Depth(ft..,Set Depth(TVD)I...Wl(leSt) Grade Top Connection GAUGE;10,4764 TUBING-41/2"x3 31/2 2.992 30.8 11,012.6 7,464.8 9.30 L-80 EUE 1/2"@120.6 Completion Details Nominal ID 111 Top(BOB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 30.8 HANGER FMC ALP HORIZTONAL HANGER(METAL TO METAL 3.958 PACKER;10,537.2 SEALS) 120.6 120.6 0.13 XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 NIPPLE;10,569.8 - 2.91" 537.3 537.2 2.80 NIPPLE CAMCO DS LANDING NIPPLE 2812 10,476.4 7,345.4 68.01 GAUGE CAMCO SLB SOLID GAUGE MANDREL 2.920 Loca7oR;t9ssss ;:` 10,537.2 7,367.2 70,15 PACKER BAKER PREMIER PACKER 2.880 WLEG,10,996 2 10,569.8 7,377.9 71.58 NIPPLE CAMCO DS LANDING NIPPLE W/RHC PLUG 2.812 10,995.2 7,462.7 8276 LOCATOR BOT FLUTED NO GO LOCATOR 3,000 10,996.2 7,462.8 82.78 WLEG BAKER WLEG 2.970 Perforations&Slots Shot m Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Dale t) Type Com 11,721.4 11,724.1 7,487.3 7,487.3 9/5/2015 PERFP Frac Port INTERMEDIATE;35.1-11,1768 a° . 12,351.4 12,354.1 7,486.0 7,486.1 9/5/2015 PERFP Frac Port 13,018.1 13,020.9 7,493.6 7,493.6 9/5/2015 PERFP Frac Port r 7 13,691.4 13,694.1 7,503.1 7,503.1 9/5/2015 PERFP Frac Port 14,359.3 14,362.1 7,505.0 7,505.0 9/5/2015 PERFP Frac Port 15,027.4 15,030.1 7,512.1 7,512.1 9/5/2015 PERFP Frac Port PERFP;17,727.4-11,724.1 _' 15,739.5 15,742.2 7,517.3 7,517.4 9/5/2015 PERFP Frac Port 16,410.8 16,413.5 7,521.2 7,521.2 9/5/2015 PERFP Frac Port PERFP;12,351.4-12,354.1 17,126.4 17,129.2 7,531.41 7,531.4 9/5/2015 PERFP Frac Port Mandrel Inserts st PERFP;13,018.1-73020.9 n' ati -- on Top(TVD) Valve latch Port Size TRO Run N Top(9KB) (NOB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com 1'. 4,196.8 3,432.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/7/2015 PERFP;13,691A 13694 1 a' 2 7,604.6 5,613.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/7/2015 3 10,417.4 7,322.5 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 2,500.0 9/7/2015 Notes:General&Safety PERFP;143593 14862 1 End Date Annotation NOTE: PERFP;15,027.4-15,030.1 PERFP;15,739.5.15,742.2 PERFP;16,410.8-16,413.5 ' r PERFP;1],126.4-77,129.1 i LINER;10,997.3-17,888.0 ConocoPhiIiips Time Log & Summary We'Mew Web Reporting Report Well Name: CD5-05 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 8/12/2015 4:00:00 PM Rig Release: 9/8/2015 1:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/12/2015 24 hr Summary Move rig from CD5-313 to CD5-05. Spot rig and rig up. RU new riser and surface lines. Test diverter-good. PJSM for spudding well. 07:00 08:00 1.00 0 0 MIRU MOVE MOB P Jack and move pipe shed away from sub. SIMOPS-Electrician disconnect lines from sub. 08:00 08:15 0.25 0 0 MIRU MOVE MOB P Move pits/motors away from sub. 08:15 09:00 0.75 0 0 MIRU MOVE MOB P Skid floor and move into position. Raise rear wind walls and support feet 09:00 12:00 3.00 0 0 MIRU MOVE MOB P Jack rig sub up and pull off of CD5-313. Remove Tie bars on sub base and crab down pad. Spot rig sub over CD5-05 conductor. 12:00 12:15 0.25 0 0 MIRU MOVE MOB P PJSM on skidding rig floor out. 12:15 13:00 0.75 0 0 MIRU MOVE MOB P Skid rig floor into drilling position. Lower rig support feet and cellar wind walls into position. 13:00 13:30 0.50 0 0 MIRU MOVE MOB P Spot Pits and Motor complexes into position. Shim and level rig sub. Move pipe shed next to sub and level. 13:30 15:45 2.25 0 0 MIRU MOVE MOB P Work on pre-spud check list. connect service lines at Interconnect. Spot Ball Mill and Pipe shed next to rig. RU to High-line. Note: rig on High-line power at 1540 hrs. 15:45 16:30 0.75 0 0 MIRU MOVE RURD P Review and finalize Rig Acceptance check list. Note: Rig accepted on day work at 1600 hrs, 8/12/15. 16:30 19:00 2.50 0 0 MIRU MOVE RURD P Load pipe shed w/17 jts 5"HWDP. RU new surface riser, flow line and hole fill lines. Hook up valves on conductor.Take on 9.0 ppg DRILPLEX mud. 19:00 19:15 0.25 -0 0 MIRU MOVE SFTY P PJSM on change out Saver sub. 19:15 21:45 2.50 0 0 MIRU MOVE RURD P Change out TD Torque Wrench heads. Change out Saver sub from XT-39 to DS50 thread. 21:45 22:45 1.00 0 0 MIRU MOVE RURD P Change elevators, prime mud pumps and install air boot on riser for drip pan. Page 1 of 26 1 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:45 23:30 0.75 0 0 MIRU MOVE BOPE P Conduct diverter test w/5"DP. Annular close in 25 sec, knife valve close in 1.13 sec,first 200 psi in 40 sec and built back to full system pressure 133 sec. Avg 4 bottle Accumulator pressure=2,000 psi. AOGCC John Crisp waived wittiness of diverter test. 23:30 00:00 0.50 0 0 MIRU MOVE SRVY P Calibrate and survey True north and wellbore heading with surface Gyro 08/13/2015 Spud well and drill 13-1/2"hole to 1,590',taking gyro check shots to 1,006'md. 00:00 00:45 0.75 0 0 MIRU MOVE SRVY P Continue to calibrate Gyro tool. 00:45 01:00 0.25 0 0 MIRU MOVE SEQP P Calibrate block height with MWD and data recorders. 01:00 01:30 0.50 0 0 MIRU MOVE RURD P PU and set 90' mouse hole. 01:30 02:15 0.75 0 0 MIRU MOVE SFTY P Pre-spud meeting with rig and service personnel. PJSM for PU BHA #1 -13-1/2"motor assembly. 02:15 04:15 2.00 0 70 MIRU MOVE BHAH P PU BHA tools and equipment to rig floor via beaver slide. MU BHA#1 - 13-1/2"motor assembly to 70'. 04:15 05:00 0.75 70 70 MIRU MOVE SEQP P Fill hole/stack with water and check for leaks-good. Pressure test mud lines to 3,500 psi-good. 05:00 12:00 7.00 70 528 SURFA( DRILL DDRL P Drill 13-1/2" hole from 144'to 528' md,TVD: 526',ADT: 3.39 hr,AST: 0.25 hr,ART: 3.14 hr Footage-414', 528 gpm, 930 psi WOB: 22K, RPM:60,TQ on/off= 3.5K/1.5K ft-lb 12:00 00:00 12.00 528 1,590 SURFA( DRILL DDRL P Drill 13-1/2" hole from 528'to 1,590', TVD: 1,584",ADT: 7.62 hr,AST: 3.58 hr,ART:4.04 hr Footage- 1,062', 550 gpm, 1,280 psi ROT= 115K lb WOB:20K, RPM:60, TQ on/off= 4.0K/1.5K ft-lb Note:took gyro check shot surveys at all connections to 1,006' 08/14/2015 Drill well to TD at+/-2,285'md. CBU 3X, flo-chk, static. BROOH and handle BHA. 00:00 11:30 11.50 1,590 2,285 SURFA( DRILL DDRL P Drill 13-1/2" hole from 1,590'to 2,285',TVD: 2,165,ADT: 9.10 hr, AST: 3.93 hr,ART: 5.17 hr Footage-695', 700 gpm, 2,250 psi ROT= 112K lb WOB: 30-35K, RPM:60,TQ on/off= 5K/2.3Kft-lb Increase MW to 9.6 ppg at 1,800' md. Page 2of26 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 13:00 1.50 2,285 2,285 SURFA( CASING CIRC P C&C mud at TD. Pump 38 bbl Nutplug sweep with 700 gpm,60 rpm. 2.3K TQ, 1,970-2,050 psi. PU= 128K, SO= 112K, ROT= 117K lb 13:00 13:15 0.25 2,285 2,285 SURFA( CASING OWFF P Flo-chk. Static 13:15 19:30 6.25 2,285 500 SURFA( CASING BKRM P BROOH from 2,285'to 1,465'at 700 gpm, 1,870-2,200 psi, 60 rpm,2-5K TQ. Continue to BROOH to 500'md, thru permafrost,with 500 gpm, 950- 1,070 psi, 1.5-3.0K TQ. Heavy cutting load over shakers from 630'to 250'. 19:30 22:30 3.00 500 161 SURFA( CASING BKRM P BROOH from 500 to BHA'at 161' with 250-400 gpm, 190-600 psi,20 rpm, 1-3K TQ. Heavy cutting load over shakers continued to 250'. Hole packed off at 276'with 20K lb overpull. 22:30 00:00 1.50 161 37 SURFA( CASING BHAH P PJSM. Flo-chk. Static. Stand back non-mag Flex DCs. LD BHA#1 to 37'. Calc Hole fill=27.61 bbl/Actual= 74 bbl. 08/15/2015 Finish LD BHA, RU and run 10.75",45.5 lb/ft, L-80, BTC x H563 csg to 2,275'. (Worked through tite spots from 275'-725'md). Circ and condition mud for cementing. Pump Lead and Tail cement, insert cement wiper plug and prep to displace.. 00:00 00:15 0.25 37 0 SURFA( CASING BHAH P LD SLB PowerPac motor 00:15 01:15 1.00 0 0 SURFA( CASING BHAH P Clean&clear floor of BHA tools& equipment. 01:15 02:45 1.50 0 0 SURFA( CASING RURD P R/U to run casing. C/O bails on top drive. C/O bushings in rotary table. M/U Volant CRT. 02:45 04:30 1.75 0 164 SURFA( CASING PUTB P PJSM. RIH 10-3/4",45.5#, L-80, Casing to 125'(Silver Bullet Shoe,2 jts, Halliburton F/C, & 1 jt 10-3/4" BTC csg)Circ and confirm floats functional 04:30 12:00 7.50 164 1,057 SURFA( CASING PUTB P Cont.to run 10-3/4"casing f/164'to 1057'. (Ran 19 jts BTC&7 jts Hyd 563 26 total jts., 1 Centek centralizer per jt) Numerous tight spots throughout-most difficult @ 278',390',428', 535-547, pump pressure spiking by 100-250 psi, Large amount of gravel across shakers to 700'.Washed down with 4 bpm 140- 170 PSI. Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:15 6.25 1,057 2,275 SURFA( CASING PUTB P Cont.to run 10-3/4"casing f/1057'to 2275' . (Ran 19 jts BTC&34 Hyd 563 total, 1 Centek centralizer per jt) Wash through tight hole f/875'to 920'.Worked through tight spots 920'to 1056', Hole conditions improved below 1100'.Washed casing down w/4 bpm avg. press.150 psi. MU FMC fluted hanger and LJ,Washed down and landed hanger with float shoe @ 2275'& FC @ 2188'. PUW 160K SOW 125K 18:15 18:45 0.50 2,275 2,275 SURFA( CEMEN'CIRC P Circ&Cond mud at 7-8 BPM, 250-280 psi 18:45 19:00 0.25 2,275 2,275 SURFA( CEMEN-RURD P PJSM. RU cement line to Volant CRT. 19:00 21:45 2.75 2,275 2,275 SURFA( CEMEN-CIRC P C&C mud for cement job. PJSM for cement job. 21:45 22:00 0.25 2,275 2,275 SURFA( CEMEN'SEQP P Shut down circulating. Line up to pump cement. Flood line with water and pressure test to 3,000 psi. 22:00 00:00 2.00 2,275 2,275 SURFA( CEMEN-CMNT P Pump 100.1 bbl of 10.5 ppg MudPush II at 4.8-5.2 BPM, 120- 210 psi. Unsting from Volant tool, insert bottom cement plug, sting in with Volant tool. Pump 471.1 bbl of 11.0 LiteCRETE Lead cement plus additives at 5.7 to 7.1 BPM, 290- 330 psi. Reciprocate pipe 6-8' throughout. Note: Had cement returns to surface after 450 bbl of Lead was pumped. Cement returns to surface after displacement was 275 bbl. 08/16/2015 Displace cement, bump plug, check cement float-failure. Hold float equip closed with applied pressure. Close Annular BOP on casing and monitor for pressure increase on the Surface X Conductor annulus. PU DP via the 90' mouse hole while waiting on cement. Bleed off applied pressure. Open Annular, lift Diverter,set slips, and cut 10-3/4"casing for Transition nipple. Page 4of26 Time Logs O • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 2,275 2,267 SURFA( CEMEN-CMNT IP Pump 60.1 bbl of 15.8 ppg"G"Tail cement at 2.7 bbl,while reciprocating pipe(PU= 195K, SO= 107K). Slowed pump rate due to pump jacking and cement line whipping in derrick. Casing string stuck 8' high while reciprocating, after 44 bbl of Tail cmt pumped. Continue pumping remaining cmt with returns to surface. (00:10 hrs). Shut down cement pump, un-sting Volant tool from casing and insert top cement plug. Sting in with Volant tool and pump 20.1 bbl of water with cement pump and shut down. Displace with rig pump at 3-6 BPM, 430-680 psi. Had partial returns during first 40 bbl pumped increasing to full returns. Slowed pumps to 3 BPM,430-450 psi for last 40 bbl of displacement. Bumped plug as calculated at 189.8 bbl pumped. Increase pressure to 940 psi and held for 5 min. (Worked pipe throughout displacement with 50-325K Ib, but no movement). Bled pressure and floats were not holding. Applied surface pressure, reseated plugs and held 940 psi on floats while WOC. Note: CIP at 01:02 hrs 8/16/15 Note; 10-3/4"Casing set at 2,267' and/2,150.5'tvd 01:30 03:45 2.25 2,267 2,267 SURFA( CEMEN-RURD P Confer with town. Prep tools and equip for setting emergency casing slips. RD Diverter line remove Knife valve and install blind flange. Casing hanger flutes were located at the Annular element. Pull casing in tension to 235K lb to locate hanger flutes above Annular element. Close Annular BOP and monitor annulus for possible pressure increase. PU 90' mouse hole and set. 03:45 12:00 8.25 2,267 2,267 SURFA( CEMEN"PULD P PJSM. PU/MU and rack back 56 stds of 5" DP via the mouse hole while WOC. Monitor Surface X Conductor annulus for pressure build-up. Page 5 of 26 Time Logs .' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 2,267 2,267 SURFA( CEMEN-PULD P PJSM. Continue to PU/MU and rack back 15 stds of 5"DP via the mouse hole while WOC. Monitor Surface X Conductor annulus for pressure build-up. No pressure increase. Install new hydraulic lines under rig floor. 17:00 22:15 5.25 2,267 2,267 SURFA( CEMEN-NUND T Open annulus with no flow or pressure. Bled off 950 psi from casing. Drain riser, LD mouse hole, lift Diverter stack,wash conductor stub out(packed off with 1-3"gravel and cement)center casing and set casing emergency slips. Release surface tension on casing to energize slips with 0.5"casing movement. 22:15 00:00 1.75 2,267 0 SURFA( CEMEN CUTP T Rough cut 10-3/4"casing. Backout Landing Jt with 1 turn, release Volant tool. LD tools and cut joint from rig floor. 08/17/2015 Flush stack and LD riser,weld on wellhead Transition nipple, Wait on weld to cool. Perform derrick inspection, Slip&Cut drill line, maintenance on drawworks and brakes, PU remaining 5"DP and MPD elements. 00:00 01:00 1.00 0 0 SURFA( CEMEN-RURD T LD 10.75"LJ, Csg Hanger and 3.76' cut joint. Set Annular and Starting head down onto conductor. 01:00 01:45 0.75 0 0 SURFA( CEMEN-RURD P RD Volant CRT, bail extensions and elevators. RU to Flush Annular 01:45 02:15 0.50 0 0 SURFA( CEMEN-WWWH P Flush Annular and riser with stack washer with 6 bpm, 10 psi and 5 rpm. LD stack washer 02:15 02:45 0.50 0 0 SURFA( CEMEN-NUND P ND riser,Annular BOP and starting head. Prep cellar for welder. 02:45 04:30 1.75 0 0 SURFA( CEMEN-NUND T Welder weld Bell nipple on casing. SIMOPs PU and install 90'mouse hole. 04:30 05:00 0.50 0 0 SURFA( CEMEN'NUND T Welder continue to weld Bell nipple on casing while LD 1 stand of NMDC via 90'MH. 05:00 06:30 1.50 0 0 SURFA( CEMEN-NUND T Continue to install wellhead while Slip and Cut 75'of drill line. 06:30 07:15 0.75 0 0 SURFA( CEMEN'NUND T Finish welding in cellar on wellhead at 07:10 hrs. Note: Pre-heated to 450 deg and held while welding. Cleaned and visually inspected for cracks-none visible. Post heated to 900 F deg evenly. Triple wrapped weld and wellhead with insulation blanket covered with Herculite and set warning cones around cellar. Page 6 of 26 Time Logs •, Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:15 09:15 2.00 0 0 SURFA( CEMEN-NUND T Wait on wellhead to cool. SIMOPs: Remove drawworks drum guards and prep for MPI inspection. Remove brake equalizer bar and remove brake linkage shaft. 09:15 11:30 2.25 0 0 SURFA( CEMEN NUND T Continue to wait on wellhead to cool. SIMOPs: Clean drawworks and prep for MPI inspection. 11:30 12:00 0.50 0 0 SURFA( CEMEN NUND T Continue to wait on wellhead to cool. SIMOPs: Clean and clear cellar area and prep tools for NU BOPE. 12:00 14:45 2.75 0 0 SURFA( CEMEN'NUND T Continue to wait on wellhead to cool. SIMOPs:Tuboscope MPI brake components-good. 14:45 18:15 3.50 0 0 SURFA( CEMEN NUND T Continue to wait on wellhead to cool. SIMOPs: Install new Equalizer bar, linkage shaft in drawworks and pin and adjust. 18:15 20:15 2.00 0 0 SURFA( CEMEN'NUND T Continue to wait on wellhead to cool. SIMOPs: Reinstall drawworks guards, ODS EZ-Torq.Adjust brakes and change out hose on Crown-O-matic. Bring MPD elements to rig floor. 20:15 00:00 3.75 0 0 SURFA( CEMEN NUND T Continue to wait on wellhead to cool. SIMOPs: PU remaining 23 stands of 5"DP(one with MPD element), via the 90' MH and stand back in derrick. Note: Rig taken off high-line power and put on generators at 21:15 hrs 8/17/15(due to field summer maint) and isolated from facilities per Energy Isolation Policy 38/18/2015 Test seal on Wellhead and Transition nipple to 1,000 psi-good. NU BOP stack. Perform BWM on BOPs, RU and test BOPE. 00:00 03:00 3.00 0 0 SURFA( CEMEN-NUND T Continue to wait on wellhead to cool. SIMOPs: LD 90'mouse hole, load shed with 4" DP. Check temp of wellhead-165 F deg. Remove one layer of blanket and wait until cool enough to work on. 03:00 03:30 0.50 0 0 SURFA( CEMEN PRTS T RU and pressure test void in Transition nipple to 250 psi with N2 and hold for 5 min. Increase pressure to 1,000 and hold for 10 min-good.. 03:30 04:30 1.00 0 0 SURFA( WHDBO NUND P Install wellhead, actuator and annulus valves. Test void to 1,000 psi for 10 min-good 04:30 05:15 0.75 0 0 SURFA( WHDBO NUND P Install DSA and Alpine speed head on wellhead. Connect Kill/Annular and Koomey lines. 05:15 07:00 1.75 0 0 SURFA( WHDBO NUND P NU BOPE stack Page 7 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:00 11:00 4.00 0 SURFA( WHDBO SVRG P Perform BWM on BOP stack-Open ram doors and wash out preventer bodies and rams-rig mechanic visually inspected all components including annular preventer-replaced one door seal on blind rams. Close and tighten bolts on ram doors. 11:00 13:00 2.00 SURFA( WHDBO MPDA P RU MPD Flow box, Flow line, mud bucket return line and trip nipple 13:00 15:00 2.00 SURFA( WHDBO MPDA P Install secondary annulus valves, hole fill hose, bleeder line, Ketch Kan, MU choke line, RU MPD valves and hoses 15:00 16:30 1.50 0 0 SURFA( WHDBO RURD P RU to test BOPE. Finish installing secondary annulus valves. Set lower Test plug and 5"test joint. Fill stack and lines with water. MU FOSV and Dart floor valves for testing. 16:30 00:00 7.50 0 0 SURFA(WHDBO BOPE P BOPE Test: Test with 5"test joint, Test Annular to 250/2,500 psi for 5 min, Test 3.5"x 6"variable UPRs, Blind rams, auto IBOP, manual IBOP, FOSV, Dart valve, needle valve, choke valves#1 -14, (tighten choke line under rig floor)and HCR Choke and Kill,4"Demco to 250/3,500 psi for 5 min. each- all good.Test all rig gas lines-Test witnessing waived by Jeff Jones of the AOGCC. 08/19/2015 Finish testing BOPE and MPD, pull test plug and install WB. PU/MU BHA#2-9-7/8"x 11" RSS, RIH and test casing to 3,500 psi, drill out cement shoe track, clean out rat hole and drill 20'of new formation to 2,305'. Perform LOT to 15.9 ppg EMW and drill ahead Intermediate hole section to 2,729'md. 00:00 01:30 1.50 0 0 SURFA(WHDBO BOPE P Continue to test 3.5"x 6"variable LPRs to 250/3,500 psi. Test Super and Manual chokes to 1,100 psi. Koomey test; IP=3,200 psi, After close= 1,525 psi,200 psi recovery 30 sec, full recovery 166 sec, N2-4 bottle average=2,050 psi. Function tested BOPE from the remote panel-good. - Test witnessing waived by Jeff Jones of the AOGCC. 01:30 03:15 1.75 0 0 SURFA( WHDBO MPDA P PJSM. RD Trip nipple and hole fill lines. Install MPD test plug and fill MPD lines with water. Test RCD head, Orbit valve, Lo-Torque#3, 5, 11 and 12 valves to 250/1,200 psi.- Good. Flush Poor Boy gas buster with 3 BPM, 160 psi. RD test equipment, pull MPD test plug and RU Trip nipple and hole fill lines. 03:15 04:00 0.75 0 0 SURFA(WHDBO RURD P Pull test plug and install 10"WB. Blow down Choke and Kill lines and manifold. Set 90' MH. Page 8 of 26 Time Logs ! • ', Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:45 1.75 0 143 SURFA( CEMEN-BHAH P PU BHA#2 to rig floor. MU BHA and RIH w/HWDP to 143' 05:45 06:00 0.25 143 696 SURFA( CEMEN-TRIP P RIH w/HWDP to 696' 06:00 06:45 0.75 696 2,008 SURFA( CEMEN TRIP P RIH w/5"DP from 696'to 2,008'. Calc/Actual=21.8/23.0 bbl displacement. 06:45 07:30 0.75 2,008 2,135 SURFA( CEMEN COCF P Wash and ream from 2,008'to 2,158' with 425 GPM, 950 psi,60 rpm, 3.5K TQ. Tag solid cement set down with 5K lb. PU= 130, SO= 123, ROT= 115K lb. PU to 2,135'. 07:30 08:15 0.75 2,135 2,135 SURFA( CEMEN PRTS P RU and test 10-3/4"csg to 3,500 psi, hold for 30 min and chart record- good. Bleed off pressure and RD test equip. 08:15 09:00 0.75 2,135 2,158 SURFA( CEMEN COCF P Wash and ream from 2,135'-2,158' with 425 gpm, 950 psi, 60 rpm and 3.5K TQ. 09:00 15:00 6.00 2,158 2,267 SURFA( CEMEN DRLG P Drill cement shoe track from 2,158' to 2,267'(FC:2,180'-2,183', FS: 2,265'-2,267'),with 300-650 gpm, 430-1,950 psi,40-70 rpm,2.0-4.5K TQ and 3-20K lb WOB. 15:00 15:15 0.25 2,267 2,305 SURFA( CEMEN'DRLG P Drill rat hole from 2,267'to 2,285'at 650 gpm, 1,840 psi, 70 rpm, 3.5- 4.5K TQ. 15:15 15:30 0.25 2,267 2,305 SURFA( CEMEN DDRL P Drill 20'of new formation to 2,305' and begin displacing hole to 9.6 ppg LSND mud at 650 gpm, 1,630 psi, 70 rpm and 4.0K TQ. 15:30 16:00 0.50 2,305 2,305 SURFA( CEMEN'DISP P Continue displacing hole to 9.6 ppg LSND and condition mud for LOT. Take SPRs. SPRs-2,135'md, 0845 hrs MP#1: 30-90,40-150 MP#2: 30-90,40-150 16:00 16:15 0.25 2,305 2,260 SURFA( CEMEN-OWFF P Pull back inside casing to 2,260'and flow-chk-static. 16:15 17:00 0.75 2,260 2,260 SURFA( CEMEN LOT P PJSM. RU lines and test equip. Perform LOT to 15.9 ppg EMW with 9.6 ppg LSND and 939 psi surface pressure. Shut in and monitor for 30 min. 17:00 17:30 0.50 2,260 2,305 INTRM1 DRILL RURD P RD test equip and blow down lines. Wash back down to 2,305'and with 650 gpm, 1600 psi,60 rpm and 4.0K TQ 17:30 19:00 1.50 2,305 2,386 INTRM1 DRILL DDRL P Drill ahead 9-7/8"Intermediate hole from 2,305'to 2,386'. PU= 125K, SO= 115K, ROT= 120K, SPP= 1,610 psi. Page 9 of 26 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 2,305 2,386 INTRM1 DRILL CIRC P Drop 1.25"reamer activation ball and pump down with 250- 150 gpm, 280- 140 psi, 30 rpm, 2.5K TQ(bit at 2,380'and UR blades at 2,274'). Increase flowrate to 650 gpm, 1,190 psi(460 psi decrease and 660 MWD turbine rpm decrease) indicated flow diverting thru reamer. PU without rotation and tag csg shoe with UR blades with 5K lb. Rotate to bottom under-reaming 11"hole to 2,275' md. 19:30 00:00 4.50 2,460 2,540 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 2,386 to 2,729'. ADT=5.51 hrs,TVD=2,487'. PU= 125K, SO= 115K, ROT= 120K, TQ on/off=4.5K/3.0K ft-lb SPRs-2,305'md, 1550 hrs MP#1: 30-30, 40-130 MP#2: 30-30, 40-120 08/20/2015 Drill ahead 9-7/8"x 11" Intermed hole section at 4,924'and 00:00 12:00 12.00 2,729 3,799 INTRM1 DRILL DDRL P "Drill 9-7/8—x 11""hole from 2,729 to 3,799'. ADT=8.84 hrs, TVD= 3,170'. PU= 138K, SO= 127K, ROT= 133K, TQ on/off=5.4K/4.0K ft-lb, ECD-10.47 ppg SPRs-3,517'md, 0855 hrs MP#1: 30- 130,40- 170 MP#2: 30- 130,40- 170 12:00 00:00 12.00 3,799 4,924 INTRM1 DRILL DDRL P "Drill 9-7/8"x 11"hole from 3,799 to 4,924'. ADT=9.37 hrs, TVD=3,900'. PU= 164K, SO= 134K, ROT= 149K, TQ on/off=8.5K/4.5K ft-lb, ECD-10.69 ppg SPRs-4,547'md, 1930 hrs MP#1: 30- 170,40-230 MP#2: 30- 170,40-240 08/21/2015 Drill ahead 9-7/8"x 11"Intermed hole section at 7,186'and 00:00 12:00 12.00 4,924 6,169 INTRM1 DRILL DDRL P "Drill 9-7/8"x 11"hole from 4,924 to 6,169'. ADT= 10.05 hrs,TVD= 4,690'. PU= 182K, SO= 145K, ROT= 160K, TQ on/off= 11.6K/6.2K ft-lb, ECD-10.67 ppg SPRs-5,582' md, 06:05 hrs MP#1: 30- 140,40- 180 MP#2: 30- 140,40- 180 Page 10 of 26 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 6,169 7,186 INTRM1 DRILL DDRL P "Drill 9-7/8"x 11"hole from 6,169 to 7,186'. ADT=9.09 hrs, TVD=5,345'. PU=225K, SO= 150K, ROT= 177K, TQ on/off= 17.8K/13.2K ft-lb, ECD-10.40 ppg SPRs-6,714'md, 18:06 hrs MP#1: 30-200,40-230 MP#2: 30-200,40-230 08/22/2015 Drill ahead 9-7/8"x 11" Intermed hole section to 9,260'md, install MPD element, drill ahead and continue increasing MW to 10.2 ppg by 9,376'. 00:00 12:00 12.00 7,186 8,420 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 7,186 to 8420'. ADT=9.8 hrs,TVD=6129'. PU=260K, S0= 155K, ROT= 190K, TQ on/off=20.5K/15K ft-lb, ECD-10.59 ppg SPRs-7,561'md, 03:30 hrs MP#1: 30-200,40-250 MP#2: 30-200,40-250 12:00 21:00 9.00 8,420 9,260 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 8,420' to 9,260'. PU=260K, S0= 155K, ROT= 190K, TQ on/off=20.5K/15K ft-lb, ECD-10.55 ppg SPRs-9,105'md, 19:52 hrs, 9.9 ppg mud MP#1: 30-240,40-280 MP#2: 30-240,40-280 Note: begin to increase MW from 9.6 to 9.9 ppg at 9,035'and 21:00 21:30 0.50 9,260 9,166 INTRM1 DRILL CIRC P Circ and stand back DP stand. Flow chk for 10 min while rotating at 20 rpm, 11.5K TQ-static. Blow down hole fill line. 21:30 22:00 0.50 9,166 9,166 INTRM1 DRILL MPDA P Pull trip nipple and install MPD element. 22:00 22:30 0.50 9,166 9,260 INTRM1 DRILL MPDA P Break in RCD bearing package with 50 rpm and 100 rpm. Function and calibrate MPD equip while reaming back to bottom. 22:30 00:00 1.50 9,260 9,376 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,260' to 9,376'. ADT=8.28 hrs,TVD=6,738'. PU=265K, S0= 170K, ROT= 170K, TQ on/off=20.1K/11.9K ft-Ib, ECD-11.07 ppg w/10.2 ppg mud. Note: Continue to increase mud wt from 9.9 to 10.2 ppg. 08/23/2015 Drill 9-7/8"x 11" Intermed hole at 9,827', POOH to 9,591'and check surveys,drill ahead to 10,731' Page 11 of 26 Time Logs , Date From To Dur S. Depth E. Depth Phase -Code Subcode T Comment 00:00 06:45 6.75 9,260 9,827 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,376' to 9,827. ADT=5.35 hrs,TVD=7015'. PU=265K, S0= 170K, ROT=200K, TQ on/off=21.1K/17.8K ft-lb, ECD-11.16 w/10.4 ppg mud wt. 06:45 09:00 2.25 9,827 9,827 INTRM1 DRILL SRVY T Initial and corrected surveys @ 9576' exceeded 5 degree DL(5.1 degrees) Pulled up to 9591'and shot survey @ 9529'MD. RIH shot survey @ 9621' MD for JORPS compliance. PUW 250/260 K SOW 165/170 K 775 gpm/2970 psi-Followed MPD ramp schedules at connections 09:00 12:00 3.00 9,827 10,014 INTRMI DRILL DDRL P Drill 9-7/8"x 11"hole from 9,827' to 10,014' ADT 2.25 hrs.TVD 7121' PU=265K, S0= 175K, ROT=202K, TQ on/off=22K/17K ft-lb, ECD-11.52 ppg w/10.6 ppg Mud Wt. SPRs- 10,014'md, 11:45 hrs, 10.6 ppg mud MP#1: 30-440/178 BP,40- 490/177 BP MP#2: 30-440/184 BP,40- 480/181 BP 12:00 00:00 12.00 10,014 10,731 INTRM1 DRILL DDRL P Drill 9-7/8"x 11" hole from 10,014' to 10,731' ADT 8.54 hrs. TVD 7,424' PU=275K, TQ on/off= 19.5K/ 17.5K ft-lb, ECD-11.52 ppg w/10.6 ppg Mud Wt. MPD-SPRs- 10,484'md, 10.6 ppg MW, 19.33 hrs, BP=202 psi MP#1: 30-480,40-520 MP#2: 30-490,40-540 08/24/2015 Drill to 9-7/8"x 11"Intermed hole section TD at 11,189', CBU at 850 gpm while reciprocating pipe. Drop ball and pump down to close Reamer. Did not close. Confer with town and proceed with circulating and increasing MW for trip margin. Flow-chk-good. Prep to Strip-OOH. 00:00 09:15 9.25 10,731 11,189 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 10,731' to 11,189' ADT 7.48 0 hrs.TVD 7481' PU=275K, SOW=160K ROT=200K TQ on/off=20.5K/18K ft-lb, ECD-11.45 ppg w/10.6 ppg Mud Wt. MPD-SPRs- 11,189'md, 10.6 ppg MW, 09:20 hrs, BP= 195 psi MP#1: 30-450,40-520 MP#2: 30-460,40-530 09:15 12:00 2.75 11,189 11,179 INTRMI CASING CIRC P Circulate and condition mud- 1st BU at 790 gpm/3450 psi, Increased rate to 850 gpm/3910 psi- 150 rpm initial reduced to 140 rpm for down hole vibration. 2937 bbls into hole clean up plan Page 12 of 26 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 11,179 11,179 INTRM1 CASING RGRP T Reduced pump rate to 420 gpm/ 1260 psi-due to wash out on discharge manifold flange#1 mud pump. Observed MPD bearing assembly leaking-trapped pressure with annular preventer and changed out assembly(45 min.)Maintained 230-250 psi on well during the change out. 14:15 15:30 1.25 11,179 11,168 INTRM1 CASING MPDA T Continue to keep annular preventer closed and changed out MPD element. Maintained 230-250 psi on well during the change out. 15:30 18:30 3.00 11,168 11,179 INTRM1 CASING CIRC P Continue to CBU at 850 gpm, 3,820 psi, 140 rpm and 15.3K TQ. 18:30 20:00 1.50 11,168 11,179 INTRM1 CASING REAM T Shut down pumps, break connection at 11,168'and drop 1-5/8"composite ball to close Reamer. Screw back in and pump ball down at 250-150 gpm, 650-480 psi, 30 rpm, 12-12.5K TQ while holding 180-190 psi back pressure with MPD. No indications seen that would indicate reamer arms retracted. Pressure remained constant after pumping 3X the necessary volume. Vary pump rates, pressures, 0-120 rpm with no pressure changes or MWD turbine rpm changes seen. No indication that Reamer tool closed. 20:00 23:30 3.50 11,168 11,144 INTRMI CASING CIRC P Concur with town and proceed to increase mud weight from 10.6 to 11.1 ppg for trip margin. Pump at 700-460 gpm, 2,700- 1,270 psi, 140-90 rpm, 18.5K- 14.3K TQ. Decrease flowrate as MW increased to control ECDs and shock and vibration in MWD tools. 23:30 00:00 0.50 11,144 11,144 INTRMI CASING OWFF P Blow down TD,open MPD Orbit valve and drain line to cellar. Flow chk for 10 min-static. Line up MPD for trip 38/25/2015 Finish Strip-OOH with MPD to HWDP and BHA. Flo-chk-good. Pull MPD element and install Trip nipple. Flo-chk-good. LD BHA#2. Clear and clean rig floor. Flush BOP stack. Set test plug change UPRs to 7-5/8" solid body rams and test. RU casing running tools. PU/MU 7-5/8"cement shoe track equip, check floats and run 7-5/8"Intermediate casing to 3,097' 00:00 08:45 8.75 11,144 787 INTRM1 CASING TRIP P Strip-OOH from 11,114' to 787'per trip schedule and without pumping. Hold back pressure with MPD. Pulled thru tight spots at 10,400'and 9,931'without problems. 08:45 09:00 0.25 787 787 INTRMI CASING OWFF P Flow-chk for 10 minutes-static. PJSM on pulling element and LD BHA. 09:00 09:45 0.75 787 697 INTRM1 CASING MPDA P Blow down MPD lines. Pull MPD element and stand back in derrick. Install Trip nipple. Page 13 of 26 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:30 0.75 697 143 INTRM1 CASING TRIP IP POOH and rack back jars and 5" HWDP. 10:30 12:15 1.75 143 0 IINTRM1 CASING BHAH P LD BHA#2. Calc/Actual Fill=98/ 112 bbl 12:15 13:00 0.75 0 0 'INTRMI CASING BOPE P Drain stack, close Blind rams. Change out UPRs to 7-5/8"solid body casing rams. SIMOPs-RU Volant Casing Running Tool, Bail extensions and casing elevators. 13:00 13:30 0.50 0 0 INTRMI CASING BOPE P Pull wear ring and set test plug. 13:30 14:15 0.75 0 0 INTRM1 CASING BOPE P RU 7-5/8"test joint,test equipment and set thin wear ring(ID- 10.375"). LD test joint. 14:15 15:00 0.75 0 0 INTRM1 CASING BOPE P RU test equip and set 7-5/8"test joint. Test Annular to 250/2,500 psi and hold for 5 min each,test upper pipe rams to 250/3,500 psi-good. 15:00 16:00 1.00 0 0 INTRMI CASING BOPE P RD test equip, pull test plug and set thin walled WR(10.375"). LD test joint. 16:00 00:00 8.00 0 3,097 INTRMI CASING PUTB P Run 7-5/8", 39 lb/ft,TN110SS, H563, R3 casing with"Silver Bullet"FS, FC with Bypass adaptor and Baffle adaptor,thread locking first 4 connections. PU and check that floats are holding-ok. CENTs on Jt #1 -10'from shoe,Jt#2-3-30'above on stop collars and 1/joint floating on #3-14. Seal Guard thread dope applied with brush and make up to the base of the triangle with and average MU torque= 19,300 ft-lb,XO and run 7-5/8"29.7 lb/ft, L-80, BTC-M, R3 csg with 6,900 ft-lb MUT with Run&Seal thread dope. Fill pipe as run. 08/26/2015 Run 7-5/8"casing to 11,175'md. Circ and Cond mud for cementing, PJSM, 00:00 12:00 12.00 3,097 9,470 INTRM1 CASING PUTB P Continue to run 7-5/8"29.7 lb/ft, L-80, BTC-M, R3 csg to 9,470'and with 6,900 ft-lb MUT with Run&Seal thread dope. Fill pipe as run. (HES Cementer II installed on top of Jt #131). 12:00 15:15 3.25 9,470 9,648 INTRMI CASING PUTB P Continue to run 7-5/8"29.7 lb/ft, L-80, BTC-M, R3 csg to 9,648'and with 6,900 ft-lb MUT with Run&Seal thread dope. 15:15 19:00 3.75 9,648 11,175 INTRM1 CASING PUTB P Continue to run 7-5/8"29.7 lb/ft, L-80, H563, R3, Dopeless csg to 11,175'and with 12,400 ft-lb MUT PU=340K, SO= 160K lb. Page 14 of 26 Time Logs 411) Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 11,175 11,175 INTRM1 CEMEN'CIRC P Circ and condition mud from 11.9 ppg to 11.1 ppg and YP from 40 to 20,while increasing flowrate from 1 - 6.5 bpm600-420 psi. Reciprocate casing while reciprocating 8-10'until PU=375K with no pipe movement 3X. Set weight down on hanger and continue to circulate. 38/27/2015 PJSM, Pump stage 1 cement job,displace, bump plug, hold pressure and check floats. Floats leaking. Pressure up, hold floats closed and WOC. Pressure up and open cement stage collar, CBU and pump stage 2 cement job. Drop closing plug, close cement stage collar. WOC, install/test csg packoff seals-good. LD 5" DP. RU to perform annulus LOT. 00:00 00:30 0.50 11,175 11,175 INTRMI CEMEN-CIRCP Continue to circ and condition mud for cementing, increasing to 7 bpm, 430 psi. Final YP=20 00:30 03:30 3.00 11,175 11,175 INTRM1 CEMEN-CMNT P PJSM on cementing. Dowell pump 3 bbls H2O and pressure test lines to 4,000 psi(good),42.3 bbls 12.0 ppg Mud Push, un-sting Volant tool and insert bypass plug, sting in, pump 93 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%inxs), un-sting Volant tool,drop top plug. Dowell displace w/10.1 bbls H20. Rig displace w/493.4 bbls 11.1 ppg LSND at 7.1 bpm, slowing to 3 bpm for final 20 bbl of displacement. Full returns at surface while pumping but not pipe reciprocation. Bump plug, increase pressure to 930 psi (500 psi over)and held for 5 min. Bleed pressure and check floats-not holding. 03:30 04:00 0.50 11,175 11,175 INTRMI CEMEN-CMNT T Trap casing pressure, check valve alignment and recheck floats-not holding. Re-bump plug and increase pressure to 910 psi and shut-in. CIP @ 03:36 hrs -1st stage cement job. 04:00 04:30 0.50 11,175 11,175 INTRM1 CEMEN-CMNT T WOC with 910 psi holding floats closed. Conduct Pre-Job for laying down drill pipe from the derrick with 90'mouse hole. 04:30 11:30 7.00 11,175 11,175 INTRM1 CEMEN-PULD P SIMOPs-RU and strip 2 MPD elements off 5"DP and LD. LD 55 stands of 5"DP from the derrick using 90'mouse hole. Monitor annulus while WOC,top off with 6.25 bbl for seepage loss. 11:30 11:45 0.25 5,631 5,631 INTRM1 CEMEN-SFTY P PJSM for 2nd stage cementing. Flow chk-static(slight drop). 11:45 13:00 1.25 5,631 5,631 INTRMI CEMEN-CIRC P Pressure up to 3,140 psi and open cement stage collar at 5,631'. Circ with 4-7 bpm, 220-440 psi Page 15 of 26 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:00 1.00 5,631 5,631 INTRM1 CEMEN'CMNT P PJSM. Cementers fill lines with water and test to 4,000 psi. pump 41 bbls 12.0 ppg Mud Push, 91 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement+additives(40% inxs). Drop closing plug and cementers displace w/10 bbls H2O. 14:00 15:15 1.25 5,631 5,631 INTRM1 CEMEN-CMNT P Rig displace w/261 bbls of 11.1 ppg LSND, at 7-3 bpm, 600-380 psi. Plug would not bump, stop and cycle pump up and down and plug finally bumped at 1,700 psi,to close stage collar. (Full returns during displacement). Bled pressure and check if stage collar holding. Flow back observed. 15:15 17:15 2.00 5,631 5,631 INTRM1 CEMEN"CMNT T Pressure back up to 2,200 psi and pressure bled to 1,680 psi in 15 min. Pressure up to 3,150psi and held for 10minutes then 3,600 psi and hold for 10 minutes. Bleed pressure and check for flow-static, no flow. 17:15 18:15 1.00 0 0 INTRM1 CEMEN'RURD P LD landing joint and Volant tool. Clear and clean rig floor. 18:15 18:45 0.50 0 0 INTRMI CEMEN-RURD P PU test joint and pull wear ring. 18:45 20:00 1.25 0 0 INTRM1 CEMEN'WWSP P Change elevators and set 7-5/8" casing packoff with 5"DP. RILDS and test packoff void to 5,000 psi for 10 min-good. 20:00 00:00 4.00 0 0 INTRM1 CEMEN'RURD T LD 5"DP via the 90'mouse hole from derrick. SIMOPs-change Upper pipe rams from 7-5/8"solid body rams to 3-1/2"x 6"VBRs. 08/28/2015 Continue to LD 5"DP via 90'mouse hole. RU to perform annulus LOT to 18.4 ppg EMW. Flush 7-5/8"x 10-3/4"annulus with 300 bbl of fresh water, followed by 84 bbl of diesel freeze protect. SI annulus. Change out Saver sub in TD. RU test equip and test BOPE. PU/MU BHA#3, RIH and pulse test MWD. Continue to RIH, tag cement stage collar at 5,633'and drill out. 00:00 01:30 1.50 0 0 INTRMI CEMEN-PULD T Continue to LD 5"DP via the 90' mouse hole from derrick. SIMOPs- RU cementers to 7-5/8"x 10-3/4" annulus, pressure test lines to 2,000 psi. Perform LOT with 11.1 ppg mud. Leak off at 7.5 bbls pumped and 842 surface pressure for 18.4 ppg EMW leak-off. SI and monitor well for 10 min-final SI pressure= 532 psi. Pump 300 bbl of fresh water and flush annulus followed by 84 bbl of diesel freeze protect.. SI and RD cementers. 01:30 03:30 2.00 0 0 INTRM1 CEMEN-RURD P Change out Saver sub from 5"to 4" XT39. RU test recording equip. 03:30 04:30 1.00 0 0 INTRM1 WHDBO RURD P Set 4"test plug and test joint. Fill stack and Choke manifold with water. RU to test BOPE. Page 16 of 26 Time Logs 4 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:15 2.75 0 0 INTRM1 WHDBO BOPE P BOPE Test: Test with 4"test joint, Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6"variable UPRs, Blind rams, auto IBOP, manual IBOP, FOSV, Dart valve, needle valve, choke valves#1 - 14, and HCR Choke and Kill,4" Demco to 250/3,500 psi for 5 min.each- all good.Test Manual and Auto choke valves on manifold to 1,100 psi.Tested gas alarms. Test witnessing waived by Bob Noble of the AOGCC. 07:15 07:30 0.25 0 0 INTRM1 WHDBO BOPE P Koomey test; IP=3,000 psi, manifold press after close= 1,500 psi,250 psi recovery 33 sec, full recovery 180 sec, N2-4 bottle average= 1,950 psi. Function tested BOPE from the remote panel-good. - Test witnessing waived by Bob Noble of the AOGCC. 07:30 10:15 2.75 0 0 INTRM1 WHDBO BOPE P Pull 4"test jt and test plug. Set 3-1/2"test jt and test plug. Fill lines with water.Test Annular to 250/2,500 psi for 5 min,Test 3.5"x 6"variable UPRs and 3.5"x 6"variable LPRs and Blind rams to 250/3,500 psi. Pull 3-1/2"test jt and test plug. Set 4-1/2"test jt and test plug. Fill lines with water.Test Annular to 250/2,500 psi for 5 min, Test 3.5"x 6"variable UPRs and 3.5"x 6"variable LPRs and Blind rams to 250/3,500 psi. 10:15 11:00 0.75 0 0 INTRM1 WHDBO RURD P Pull 4-1/2"test jt and test plug. Blow down lines and RD test equip. Prep wear rig, run and set 7.125"ID WR. 11:00 14:15 3.25 0 378 INTRM1 CEMEN'BHAH P MU BHA#3-6-1/2" RSS to 182' 14:15 15:15 1.00 182 1,507 INTRM1 CEMEN-PULD P PU 4"DP from pipe shed and RIH from 378-1507'. Fill pipe. 15:15 16:15 1.00 1,507 1,507 INTRM1 CEMEN-DHEQ P Shallow hole test MWD with 224 gpm, 1,030 psi at 1,507'-good. 16:15 21:15 5.00 1,507 5,484 INTRM1 CEMEN-PULD P PU 4"DP from pipe shed and RIH from 1,507-5,484'. Fill pipe every 3,000'. 21:15 22:15 1.00 5,484 5,484 INTRM1 CEMEN-PRTS P CBU. RU test equip and test 7-5/8" csg to 1,000 psi and hold for 10 min- good. Bleed off pressure and RD test equip. 22:15 22:30 0.25 5,484 5,578 INTRM1 CEMEN-PULD P PU 4"DP from pipe shed and RIH from 5,484-5,578'. 22:30 00:00 1.50 5,578 5,633 INTRM1 CEMEN COCF P Wash down and tag up on top of cement stage collar at 5,633'md. Rotate and drill collar with 2-10K WOB,40-60 rpm, 5.8K TQ PU= 145K, S0= 107K, ROT= 124K. TQ on/off=5.8K ft-lb Page 17 of 26 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08/29/2015 24 hr Summary Continue to RIH picking up DP.Tag up on cement stage collar and drillout from 5,633-4'. Pressure test casing /stage collar to 1,000 psi-good. Continue to RIH picking up 4"DP to 10,898'md.Test csg to 3,500 psi- good. Cut and slip drill line, service rig. Drill out cement shoe track and 20'of new formation. Perform FIT to 12.4 ppg EMW. Drill ahead 6-1/2"production hole section to 11,535' 00:00 00:30 0.50 5,632 5,634 INTRM1 CEMEN-DRLG P Rotate and drill cement stage collar from 5,632-34' with 2-10K WOB, 40-60 rpm, 5.8K TQ PU= 145K, SO= 107K, ROT= 124K. TQ on/off= 5.8K ft-lb 00:30 01:00 0.50 5,634 5,768 INTRMI CEMEN REAM P Wash and ream down from 5,634'to 5,768',with 200 gpm, 1,260 psi,60 rpm, 5.3K TQ,to locate BHA below cementer. 01:00 01:45 0.75 5,768 5,768 INTRMI CEMEN CIRC P CBU at 200 gpm, 1,270 psi, 60 rpm, 5.5K TQ. 01:45 02:15 0.50 5,768 5,768 INTRM1 CEMEN PRTS P Test casing to 1,000 psi for 10 min.- good. 02:15 02:45 0.50 5,768 5,945 INTRM1 CEMEN'PULD P PU 4"DP from pipe shed and RIH from 5,768-5,945'taking 20K lb in weight. 02:45 03:15 0.50 5,945 6,052 INTRM1 CEMEN-REAM P Wash and ream down from 5,945'to 6,052'with 190 gpm, 1,190 psi, 60 rpm, 5.8K TQ. 03:15 08:30 5.25 6,052 10,516 INTRM1 CEMEN-PULD P PU 4"DP from pipe shed and RIH from 6,052- 10,516'hitting tight spot and taking weight. 08:30 09:00 0.50 10,516 10,898 INTRM1 CEMEN"PULD P PU 4"DP from pipe shed and RIH from 10,516-10,898'. 09:00 10:15 1.25 10,898 10,898 INTRM1 CEMEN'PRTS P Test casing to 3,500 psi for 30 min. - good. 10:15 11:15 1.00 10,898 10,898 INTRM1 CEMEN'SLPC P Slip&Cut 60'of drill line and hold After action Review. 11:15 11:45 0.50 10,898 10,898 INTRM1 CEMEN-SVRG P Service Top Drive-grease and add hydraulic oil 11:45 12:00 0.25 10,898 10,898 INTRM1 CEMEN-SVRG P Calibrate block height. 12:00 14:15 2.25 10,898 11,044 INTRM1 CEMEN-COCF P Wash and ream cement stringers from 10,898'to 11,044'with 200 gpm, 1,930 psi, 40 rpm. 13K TQ. Tag up on Baffle Adaptor at 11,044' 14:15 15:00 0.75 11,044 11,089 INTRMI CEMEN-COCF P Wash and ream cement from 11,044' to 11,089'with 190 gpm, 1,540 psi, 50 rpm. 13.3K TQ.Tag up on Float Collar at 11,089' 15:00 16:00 1.00 11,089 11,117 INTRM1 CEMEN-DRLGP Wash and ream cement from 11,089' to 11,117'with 220 gpm, 1,770 psi, 40 rpm. 13.5K TQ. Drill out btm of Float Shoe at 11,177 16:00 16:30 0.50 11,117 11,209 INTRM1 CEMEN DDRL P Drill 20'of new formation from 11,117' to 11,209'with 240 gpm, 3,070 psi, 60 rpm, 13.7K TQ. Pump 40 bbl Hi-Vis spacer and Begin displacement of 11.1 ppg LSND mud with 9.2 ppg ProFlo mud systems. 16:30 18:00 1.50 11,209 11,150 INTRM1 CEMEN-DISP P POOH slowly from 11,209\'to 11,150'displacing 11.1 ppg LSND with 461 bbl of 9.2 ppg FloPro. Page 18 of 26 Time Logs4110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 11,150 11,150 INTRM1 CEMEN.FIT P RU test equipment and perform FIT to 12.4 ppg EMW. 18:30 19:15 0.75 11,150 11,150 PROD1 DRILL MPDA P PJSM. Pull Trip Nipple, and install MPD element 19:15 19:30 0.25 11,150 11,209 PROD1 DRILL REAM P Wash and ream back to bottom at 11,209'with 240 gal, 1,930 psi, staging up RPMs from 20-140 with 10.2K to 13.2K TQ, breaking in MPD bearings. 19:30 00:00 4.50 11,209 11,535 PROD1 DRILL DDRL P Drill 6-1/2"hole from 11,209'to 11,535'. ADT=3.63 hrs,TVD= 7,497'. PU=225K, S0= 125K, ROT= 164K, TQ on/off= 14.0K/13.5K ft-lb, ECD- 9.92 ppg SPRs- 11,097' md, 1600 hr MP#1: 20-520, 30-820 MP#2: 20-520, 30-920 38/30/2015 Drill ahead 6-1/2"Prod hole section 12,900'. 00:00 01:30 1.50 11,535 11,661 PROD1 DRILL DDRL P Drill6-1/2"hole from 11,535'to 11,661'. ADT= 1.24 hrs,TVD= 7,486'. 01:30 02:30 1.00 11,661 11,661 PROD1 DRILL SRVY T Initial and corrected surveys @ 11,504'exceeded 5 degree DL. POOH pumping only and resurveyed with 1/2 stand stations for JORPS compliance. 02:30 12:00 9.50 11,535 12,488 PROD1 DRILL DDRL P Drill 6-1/2"hole from 11,661'to 12,488'. ADT=6.95 hrs,TVD= 7,486'. PU= 198K, SO= 130K, ROT= 160K, TQ on/off=9.5K/7.5K ft-lb, ECD- 10.73 ppg SPRs- 12,318'md, 1000 hr MP#1: 20-730, 30-960 MP#2: 20-740, 30-960 12:00 14:15 2.25 12,488 12,710 PROD1 DRILL DDRL P Drill 6-1/2"hole from 12,488'to 12,710'. ADT= 1.85 hrs,TVD= 7,489'. 14:15 18:00 3.75 12,710 12,710 PROD1 DRILL CIRC T CBU at 12,710'with 250 gpm,2,350 psi, 100 rpm, 8.1 TQ. Turn pump off and bleed pressure with 15 rpm, 8.2K TQ. Close MPD choke and monitor well. Surface pressure increased to 280 psi within 3 minutes with 9.6 ppg MW.Terminated test. Decision made to increase MW to 9.8 ppg. C&C mud adding NaCI brine and SafeCarb to raise MW. 18:00 18:30 0.50 12,710 12,710 PROD1 DRILL OWFF T Turn mud pump off with 9.8 ppg mud in hole. Bleed pressure to zero and continue rotation at 15 rpm, 7.2K TQ. Close MPD choke and pressure increased to 225 psi in 5 min. Page 19 of 26 1 Time Logs ! • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:30 3.00 12,710 12,710 PROD1 DRILL WAIT T CBU at 12,710'with 250 gpm,2,360 psi,50 rpm,6.7K TQ. Reduce rotary speed to 20 rpm to reduce wear on MPD element. Wait on delivery of 245 bbl, 12.1 ppg NaBr fluid to increase MW to 10.3 ppg. Note: No gas influx while pumping with 10.7 ppg ECDs, background mud gas decreased from 1,500 units to<100 units while circulating. 21:30 00:00 2.50 12,710 12,900 PROD1 DRILL DDRL P Drill 6-1/2"hole from 12,710'to 12,900'. ADT=4.01 hrs,TVD= 7,492'. PU= 195K, SO= 125K, ROT= 160K, TQ on/off= 11.3K/9.3K ft-lb, ECD- 11.15 ppg SPRs-12,710'md, 2100 hr MP#1: 20-820, 30- 1,080/BP 90 MP#2: 20-820, 30- 1,060/BP 90 MW=9.6 ppg, begin weight up to 10.3 ppg at 00:18 hrs 08/31/2015 Drill ahead 6-1/2" Prod hole section to 12,996', increase mud weight to 10.1 ppg, close MPD choke and monitor pressure build up to 76 psi in 10 min. Drill ahead closing MPD choke on connections to 14,976'md. 00:00 01:15 1.25 12,900 12,996 PROD1 DRILL DDRL P Drill 6-1/2"hole from 12,900'to 12,996'. ADT= 1.21 hrs,TVD= 7,492'. Start weighting up to 10.1 ppg MW while drilling down. 01:15 02:00 0.75 12,996 12,996 PROD1 DRILL CIRC T Finish weight up from 9.8 to 10.1 ppg MW by adding NaBr to the system. C&C mud at 250 gpm, 2,520 psi, 100 rpm and 11K TQ until mud in balance. 02:00 03:30 1.50 12,996 13,091 PROD1 DRILL DDRL P Drill 6-1/2"hole from 12,996'to 13,091'. ADT=0.99 hrs,TVD= 7,494'. ECD= 11.6-11.7 ppg 03:30 03:45 0.25 13,091 13,091 PROD1 DRILL OWFF P Shut down mud pump and monitor well. Close MPD choke and monitor pressure build up to 76 psi in 10 minutes while rotating at 15 rpm. 03:45 12:00 8.25 13,091 13,800 PROD1 DRILL DDRL P Drill 6-1/2"hole from 13,091'to 13,800'. ADT=5.97 hrs,TVD= 7,503'. PU= 197K, S0= 126K, ROT= 158K, TQ on/off= 10.9K/10.3K ft-lb, ECD- 11.15 ppg SPRs- 13,759'md, 1100 hr, 10.1 ppg MW MP#1: 20-900,30- 1,150 MP#2: 20-820,30-1,160 Page 20 of 26 Time Logs 1111 Date From To Dur S. Depth E.Depth Phase Code Subcode T .Comment 12:00 00:00 12.00 13,800 14,976 PROD1 DRILL DDRL P Drill 6-1/2"hole from 13,800'to 14,976'. ADT=8.80 hrs,TVD= 7,511'. PU=205K,SO= 135K, ROT= 165K, TQ on/off= 11.1K/8.3K ft-lb, ECD- 11.7 ppg SPRs-14,885'md, 2200 hr, 10.1 ppg MW MP#1: 20-890,30- 1,140 MP#2: 20-860,30- 1,120 09/01/2015 Drill ahead f/14,976'to 17,145' 00:00 12:00 12.00 14,976. 16,183 PROD1 DRILL DDRL P Drill 6-1/2"hole f/14,976'to 16,183'. ADT=8.63 hrs,TVD=7,521'. PU=220K, SO= 138K, ROT= 175K, TQ on/off= 11.5K/7.7K ft-Ib, 120 RPM, 250 GPM,2910 PSI, ECD- 11.9 ppg SPRs-15,802'md, 0800 hr, 10.1 ppg MW MP#1: 20-990, 30- 1290 PSI MP#2: 20-990, 30- 1270 PSI 12:00 00:00 12.00 16,183 17,145 PROD1 DRILL DDRL P Drill 6-1/2"hole f116,183'to 17,145'. ADT=9.03 hrs, TVD=7,531'. PU=225K, SO= 130K, ROT= 173K, TQ on/off= 12.7K/8.1K ft-lb, 120 RPM,260 GPM, 3260 PSI, ECD- 12.09 ppg SPRs- 16,851'md,2045 hr, 10.1 ppg MW MP#1: 20- 1000, 30-1320 PSI MP#2: 20- 1060, 30-1360 PSI 09/02/2015 Drill ahead to TD of 17,900'. Circ hole clean for 4 B/U. Displace to 10.7 ppg Viscosified Brine. 00:00 08:00 8.00 17,145 17,569 PROD1 DRILL DDRL P Drill 6-1/2"hole f/17,145'to 17,569. ADT=6.2 hrs, TVD=7,529'. PU=212K, SO= 127K, ROT= 168K, TQ on/off= 12.9K/8.5K ft-Ib, 140 RPM, 250 GPM, 3070 PSI, ECD- N/A MWD Failure @ 17,519 08:00 10:00 2.00 17,569 17,569 PROD1 DRILL CIRC T Truoble shoot MWD tool failure.Try various pump rates&pump high vis sweep with no success. Decesion made to cont. to drill ahead blind. .... ................. Page 21 of 26 Time Logs , Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:00 14:15 4.25 17,569 17,900 PROD1 DRILL DDRL P Drill 6-1/2"hole f/17,569'to 17,900.° ADT=3.39 hrs, TVD=7,529'. PU=212K, SO= 127K, ROT= 168K, TQ on/off= 12.9K/8.5K ft-lb, 140 RPM, 250 GPM, 3070 PSI, ECD- N/A SPRs- 17,709'md, 1200 hr, 10.1 ppg MW MP#1: 20-1050, 30-1350 PSI MP#2: 20-1050, 30-1350 PSI MWD Failure @ 17,519, called TD short @ 17,900' 14:15 20:00 5.75 17,900 17,900 PROD1 CASING CIRC P Circ hole clean for 4 B/U w/250-270 GPM @ 3050 PSI. 140 RPM @ 11.8 k trq 20:00 20:15 0.25 17,900 17,900 PROD1 CASING OWFF P Perform MPD fingerprint. 125 PSI in 10 min. Calculate 10.4 ppg reservoir pressure.Will add 0.3 ppg trip margined. 20:15 21:45 1.50 17,900 17,900 PROD1 CASING CIRC P Cont.to circ w/265 GPM @ 3070 PSI&prep pits for displacement. PJSM on displacement. 21:45 00:00 2.25 17,900 17,900 PROD1 CASING DISP P Displace 10.1 ppg FloPro with 10.7 ppg Viscosified brine w/270 GPM @ 2270 PSI. Rotate 140 rpm until MPD bearing started leaking. Reduce to 75 RPM for remainder of displacement. 39/03/2015 Cont. to displace adding lube to open hole. . F/C. C/O MPD bearing. Strip OOH f/17,900'to 17,137'. Drag trends increasing. RIH f/17,137'to 17,900'. Circ hole clean&increase lubes. Strip OOH f/17,900'to 11,089'. Circ 1 B/U. Strip OOH f/11,089'to 1,320' 00:00 01:00 1.00 17,900 17,900 PROD1 CASING,CIRC P Circ&cond brine. Increase lube concentration to 3%in open hole w/270 GPM @ 2160 PSI, 75 RPM @ 9.3 k trq. PJSM on C/O MPD bearing. 01:00 01:30 0.50 17,900 17,900 PROD1 CASING OWFF P F/C(static) 01:30 02:15 0.75 17,900 17,900 PROD1 CASING MPDA P C/O MPD bearing. Drop 2.37"OD hollow drift. 02:15 03:15 1.00 17,900 17,137 PROD1 CASING TRIP P Strip OOH as per MPD schedule f/17,900'to 17, 137'. Initial P/U 220K. Drag trends increase 10K over 7 stands to 230K 03:15 03:45 0.50 17,137 17,900 PROD1 CASING TRIP T RIH f/17137'to 17,900' 03:45 05:15 1.50 17,900 17,900 PROD1 CASING CIRC T Circ&cond mud w/275 GPM @ 2200 PSI, 140 RPM @ 10.5 k. Increase lube concentration to 3%in entire system. (2%776&1%Lotorq) 05:15 05:45 0.50 17,900 17,900 PROD1 CASING OWFF T F/C(static). Line up MPD equipment. 05:45 06:15 0.50 17,900 17,137 PROD1 CASING TRIP T Strip OOH as per MPD schedule f/17,900'to 17,137' 06:15 13:45 7.50 17,137 11,089 PROD1 CASING TRIP P Strip OOH as per MPD schedule f/17,137'to 11,089' Page 22 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 14:45 1.00 11,089 11,089 PROD1 CASING CIRC P Circ B/U w/272 GPM @ 1480 PSI, 100 RPM @3.5ktrq 14:45 15:00 0.25 11,089 11,089 PROD1 CASING OWFF P F/C(static) 15:00 15:30 0.50 11,089 11,089 PROD1 CASING CIRC P Pump 30 bbls 12.1 ppg dry job. 15:30 18:30 3.00 11,089 6,905 PROD1 CASING TRIP P Strip OOH as per MPD schedule f/11,089'to 6,905' 18:30 00:00 5.50 6,905 1,320 PROD1 CASING PULD P Strip OOH as per MPD schedule f16,905'to 1,320'while laying down 4" 14#DP. 09/04/2015 Cont.to strip OOH while L/D 4" 14#DP to 1,038'. Pull MPD bearing&install trip nipple. Cont.to POOH& L/D BHA. R/U&run 4 1/2"liner 6854'. M/U LinerHanger/Packer assy. RIH w/liner on DO to 11,174'Brk. Cont. Miner in open hole to 16,746' 00:00 00:30 0.50 1,320 1,038 PROD1 CASING PULD P Strip OOH as per MPD schedule f/1,320'to 1,038'while laying down 4" 14#DP. 00:30 00:45 0.25 1,038 1,038 PROD1 CASING OWFF P F/C(static)-PJSM on MPD Bearing 00:45 01:30 0.75 1,038 1,038 PROD1 ,CASING MPDA P Remove MPD bearing&install trip nipple 01:30 02:30 1.00 1,038 317 PROD1 CASING TRIP P POOH on elevators on TT while laying down 4"DP f/1038'to 317' 02:30 02:45 0.25 317 317 PROD1 CASING OWFF P F/C(static)-PJSM on BHA 02:45 04:30 1.75 317 0 PROD1 CASING BHAH P L/D BHA#3 as per SLB 04:30 05:00 0.50 0 0 PROD1 CASING BHAH P Clean&clear floor of BHA tools& equipment. 05:00 06:15 1.25 0 0 COMPZ CASING RURD P R/U to run 4 1/2"liner. R/U power tongs. C/O air boot on trip nipple. 06:15 17:00 10.75 0 6,854 COMPZ CASING PUTB P RIH 4 1/2" 12.6#L-80 IBTM liner. (shoe, perf pup, 9 frac sleeves, 1 sliding sleeve)to 6,854' 17:00 18:00 1.00 6,854 6,899 COMPZ CASING OTHR P C/O elevators. M/U liner hanger/packer assembly. Mix&pour pal mix. M/U XO to 1 stand 4" DP. 18:00 18:15 0.25 6,899 6,899 COMPZ CASING CIRC P Break circ w/3 BPM @ 200 PSI. PU wt 125K, SO wt 105K 18:15 20:30 2.25 6,899 11,174 COMPZ CASING RUNL P RIH w/liner on DP(/6899'to 11,174'. 20:30 21:00 0.50 11,174 11,174 COMPZ CASING CIRC P Break circ w/5 BPM @ 680 PSI. PU wt 175K, SO wt 135K. Pump 20 bbls 11.7 ppg dry job to keep fluid from overflowing top of DP while RIH. 21:00 00:00 3.00 11,174 16,746 COMPZ CASING RUNL P RIH w/liner on DP f/11,174'to 16,746' 09/05/2015 Run liner on DP to 17,888'. Displace to non viscosified 10.7ppg brine. Set liner hanger/packer&test. Circ B/U. Slip&cut drill line. POOH&L/D DP. L/D liner running tools. R/U to Run 3 1/2"upper completion. 00:00 01:00 1.00 16,746 17,888 COMPZ CASING RUNL P Cont. to RIH liner on DP f/16,746'to set depth of 17,888', PU wt 225K, SO wt 145K 01:00 04:45 3.75 17,888 17,888 COMPZ CASING DISP P PJSM&displace to 10.7 ppg non viscosified NaCI/NaBr Brine w/4.5 BPM @ 1000-1100 PSI. Reciprocate pie 20'. PU wt 225K, SO wt 145- 135K Page 23 of 26 Time Logs . . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:45 1.00 17,888 10,997 COMPZ CASINGIPACK P F/C(static)Drop 1.75"ball w/3 bpm. On seat @ 856 stks. Pressure up to 3000 psi&set hanger. Confirm set& dis-engage dogs. Set packer w/70K on hook. Confirm set. 4 1/2"shoe @ 17,888'&TOL 10,997' 05:45 06:15 0.50 10,997 10,997 COMPZ CASING PRTS P Test liner top packer to 2000 PSI& chart for 10 min(good) 06:15 06:30 0.25 10,997 10,776 COMPZ WELLPF TRIP P POOH&pull out of liner f/10,997'to 10776' 06:30 07:45 1.25 10,776 10,776 COMPZ WELLPF CIRC P Circ B/U w/8 BPM @ 1940 PSI, reciprocate pipe. 07:45 09:15 1.50 10,776 10,776 COMPZ WELLPF SLPC P Slip&cut 60'drill line. Monitor well on TT. 09:15 10:15 1.00 10,776 10,776 COMPZ WELLPF SVRG P NOV perform CATT 3 Mast inspection 10:15 21:00 10.75 10,776 0 COMPZ WELLPF PULD P POOH while L/D 4" DP f/10,776'. L/D liner running tools. (Racked back 22 stands of 15.7#4"DP for next well) Calc Hole Fill 75.8 bbls/Act Hole Fill 91.5 bbls 21:00 23:00 2.00 0 0 COMPZ RPCOM RURD P R/U to run 3 1/2"upper completion. R/U power tongs, I-Wire&sheaves. Stage cannon clamps on rig floor. P/U hanger to rig floor. SIMOPS- Adjust top drive alignment 23:00 23:30 0.50 0 0 COMPZ RPCOM SVRG P Service Rig. SIMOPS-Adjust top drive alignment 23:30 00:00 0.50 0 0 COMPZ RPCOM RGRP T Adjust top drive alignment 09/06/2015 Adsjust top drive alignment. Install 9"ID wear ring. Run 3 1/2"upper completion to 10,844' 00:00 00:30 0.50 0 0 COMPZ RPCOM RGRP T Adjust top drive alignment 00:30 01:00 0.50 0 0 COMPZ RPCOM RURD P Install 9"ID wear ring 01:00 00:00 23.00 0 10,844 'COMPZ RPCOM PUTB P PJSM. Run 3 1/2"9.3#L-80 GLM upper completion to 10,844' (Test I-wire 917', 1,701',2,486', 3,267',4,084', 7,231', 8,003', 8,773', 9,543', 10,313') 09/07/2015 Cont.to run 3 1/2"upper completion. Tag fully located @ 11,013'. POOH&L/D space out jts of 3 1/2"tubing. M/U space out pup,4 1/2"tubing to Land jt B. Pull wear ring. M/U hanger&Land jt A.Terminate I-Wire. Spot CI Brine. Land on hanger. Set Packer. Pressure test tubing&IA. Set TWC. N/D BOPE&Terminate I-Wire thru well head. 00:00 00:45 0.75 10,844 11,013 COMPZ RPCOM PUTB P Cont.to run 3 1/2"upper completion and land fully located @ 11,013'. (348 jts total)PU wt 135K, SO wt 105K 00:45 01:30 0.75 11,013 10,981 COMPZ RPCOM HOSO P POOH 5jts 3 1/2"tubing f/11,013'to 10,888'. M/U 2'3 1/2"pup jt&2 jts 4 1/2"Hyd 563. 01:30 03:30 2.00 10,981 10,981 COMPZ RPCOM RURD P M/U landing jt B&pull 9"ID wear ring. L/D landing jt B Page 24 of 26 Time Logs i' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 10,981 10,981 COMPZ RPCOM'THGR P M/U tubing hanger to landing Jt A. Orient hanger w/9 O'Clock timed collar.Terminate I wire thru hanger& test swedge lock connection to 5000 psi for 10 min. SIMOPS-Spot 45 bbls CI brine inside tubing. 05:00 05:30 0.50 10,981 11,009 COMPZ RPCOM CRIH P RIH to 3'above landed @ 11,009'and displace CI brine @ 3 bpm @ 300 psi&spot from bottom of WLEG to bottom of Lower most GLM w/893 stks 05:30 07:45 2.25 11,009 11,012 COMPZ RPCOM THGR P RIH 3'and land on hanger 1'from fully located @ 11,012'. RILDS&test hanger seals to 250/5000 psi for 5 min on chart(good). 07:45 10:45 3.00 11,012 11,012 COMPZ RPCOM PRTS P Drop ball&rod. R/U to pump down tubing. Pressure test lines to 4000 psi(good).Test tubing to 3500 psi& set packer(good). Bleed tubing to 2000 psi&pressure up on annulus to 3500 psi(good). Bleed off tubing& annulus. Pressure up on annulus to 2750 psi&shear SOV in lower GLM. (good) 10:45 11:00 0.25 0 0 COMPZ RPCOM OWFF P F/C-Brine appears to be aired up. 11:00 11:30 0.50 0 0 COMPZ RPCOM RURD P B/D&R/D circ lines. 11:30 13:30 2.00 0 0 COMPZ WHDBO MPSP P L/D landing jt A&install TWC. Install landing jt B Test in direction of flow to 2500 psi for 15 min (good). L/D landing jt B 13:30 13:45 0.25 0 0 COMPZ WHDBO OWFF P F/C(static)SIMOPS-B/D kill line& mud lines. 13:45 14:45 1.00 0 0 COMPZ WHDBO MPSP T Observe slight peculation in BOPE stack. No volume increase. R/U testing equipment&attempt to pressure up on IA to 1000 psi. Fluid volume in stack rising (TWC leaking) 14:45 15:45 1.00 0 0 COMPZ WHDBO OWFF T F/C.Well continued to peculate. SIMOPS-P/U BHA tools& equipment for next well. 15:45 16:00 0.25 0 0 COMPZ WHDBO MPSP T FMC pull TWC 16:00 17:00 1.00 0 0 COMPZ WHDBO CIRC T Reverse circulate B/U w/2bpm @ 710 psi 17:00 18:00 1.00 0 0 COMPZ WHDBO MPSP T F/C. (static)Set TWC. Install landing jt B.Test TWC in direction of flow to 2500 psi for 15 min(good) 18:00 19:00 1.00 0 0 COMPZ WHDBO OWFF T F/C(static. SIMOPS-remove bell guide on top drive&B/D lines 19:00 20:45 1.75 0 0 COMPZ WHDBO MPDA P Remove trip nipple. N/D MPD valves on BOPE. Remove flow box and ketch kan 20:45 23:15 2.50 0 0 COMPZ WHDBO NUND P N/D BOPE&speed head adaptor& rack back on pedestal. SIMOPS- C/O saver sub on top drive. Page 25 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 0 0 COMPZ WHDBO NUND P SLB&FMC termintae I-Wire on well head. SIMOPS-C/O saver sub on top drive. 09/08/2015 Cont.to terminate I-Wire thru well head. N/U tree&test.Freeze protect. Prep for rig move. Set BPV. Secure well. Prep for Move. Release rig @ 13:00 hrs (Tubing&IA 350 psi OA 150 pis SLB-SGM 4091 psi @ 161* 00:00 01:00 1.00 0 0 COMPZ WHDBO NUND P SLB&FMC termintae I-Wire on well head. SIMOPS-C/O saver sub on top drive. 01:00 03:30 2.50 0 0 COMPZ WHDBO NUND P NU tree.Test tubing void to 5000 psi for 10 min(good).Test tree to 250/5000 psi&chart for 5 min (good). SIMOPS-Prep for rig move. Clean pits. R/U to freeze protect. 03:30 04:00 0.50 0 0 COMPZ WHDBO MPSP P FMC pull TWC 04:00 08:00 4.00 0 0 COMPZ WHDBO FRZP P PT lines to 2500 psi. Dowell pump 89 bbls diesel freeze protect. Let balance in cellar across squeeze manifold. SIMOPS-B/D&R/D lines. SIMOPS-Disconnect service lines &B/D steam lines. Move ball mill& pits/motors complex away from sub. Prep to move sub. 08:00 12:00 4.00 0 0 COMPZ WHDBO MPSP P FMC set BPV&test in direction of flow to 2500 psi for 15 min. SIMOPS -Cont.to move ball mill& pits/motors complex. Prep to skid floor&move sub. Well Secure @ 12:00 hrs Tubing/IA @ 350 psi&OA @ 150 psi SLB-SGM @ 4091 psi/161* _ 12:00 13:00 1.00 0 0 DEMOB MOVE RURD P Clear lines from test pump&R/D testing equipment. Remove annulus valve&install blind flange. Prep to skid floor. Page 26 of 26 • • NADConversion Western North Slope CD5 Alpine West Pad CD5-05 Definitive Survey Report 24 September, 2015 NAD 27 0 Schlumberger • Definitive Survey ReportT _---.-,,,:-_,....„- Company: .vim Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-05 Well Position +N/-S 0.00 usft Northing: 5,965,893.83 usfi Latitude: 70° 18'50.136 N +E/-W 0.00 usft Easting: 349,462.32 usfi Longitude: 151° 13'12.298 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 34.30 usft Wellbore CD5-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/14/2015 18.06 80.83 57,473 Design CD5-05 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 152.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.40 1,006.40 CD5-05 Srvy#1 GYD-GC-MS(CD5-05) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 10:52 1,036.18 2,233.29 CD5-05 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:3E 2,321.66 11,125.15 CD5-05 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 11:4C 11,219.18 17,458.41 CD5-05 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/10/2015 11:2 17,900.00 17,900.00 CD5-05 Srvy#5-Blind Surveys to TD(C BLIND Blind drilling 9/23/2015 3:5 -r s ,_ .,. =r .� n ammmaw U �• <yra�en�n�o�mmmn;mnmrn,aM i anNl Survey ,,,,,,,,_____,,,,,,,,,,,,,„r„,„,,,,, Map Map Vertical I' � � �� MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.70 0.00 0.00 36.70 -34.30 0.00 0.00 5,965,893.83 349,462.32 0.00 0.00 UNDEFINED 115.50 0.09 323.04 115.50 44.50 0.05 -0.04 5,965,893.89 349,462.28 0.12 -0.06 GYD-GC-MS(1) NOT an Actual Survey 20"x 42" 170.00 0.16 323.04 170.00 99.00 0.15 -0.11 5,965,893.98 349,462.21 0.12 -0.18 GYD-GC-MS(1) 261.00 0.24 319.82 261.00 190.00 0.40 -0.31 5,965,894.24 349,462.01 0.09 -0.50 GYD-GC-MS(1) 352.00 0.53 32.27 352.00 281.00 0.90 -0.21 5,965,894.73 349,462.12 0.56 -0.89 GYD-GC-MS(1) 446.00 1.36 2.78 445.98 374.98 2.38 0.08 5,965,896.21 349,462.44 1.00 -2.06 GYD-GC-MS(1) 537.00 2.80 4.18 536.92 465.92 5.67 0.29 5,965,899.50 349,462.72 1.58 -4.87 GYD-GC-MS(1) 629.00 3.45 359.33 628.78 557.78 10.68 0.42 5,965,904.51 349,462.95 0.76 -9.23 GYD-GC-MS(1) 724.00 4.42 351.29 723.56 652.56 17.16 -0.17 5,965,910.99 349,462.49 1.17 -15.23 GYD-GC-MS(1) 817.00 6.30 346.15 816.15 745.15 25.66 -1.93 5,965,919.52 349,460.90 2.08 -23.56 GYD-GC-MS(1) 9/24/2015 8:40:40AM Page 2 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey 141, 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 912.00 8.23 349.75 910.38 839.38 37.41 -4.39 5,965,931.32 349,458.68 2.09 -35.09 GYD-GC-MS(1) 1,006.00 10.18 357.54 1,003.17 932.17 52.33 -5.94 5,965,946.27 349,457.42 2.46 -49.00 GYD-GC-MS(1) 1,036.18 10.17 358.79 1,032.88 961.88 57.66 -6.11 5,965,951.60 349,457.36 0.73 -53.78 MWD+IFR-AK-CAZ-SC(2) 1,128.82 11.64 6.28 1,123.85 1,052.85 75.13 -5.26 5,965,969.05 349,458.56 2.20 -68.81 MWD+IFR-AK-CAZ-SC(2) 1,222.78 12.43 11.54 1,215.74 1,144.74 94.46 -2.20 5,965,988.31 349,462.01 1.44 -84.44 MWD+IFR-AK-CAZ-SC(2) 1,317.28 13.55 18.16 1,307.83 1,236.83 114.95 3.28 5,966,008.68 349,467.90 1.97 -99.95 MWD+IFR-AK-CAZ-SC(2) 1,412.02 14.94 23.33 1,399.66 1,328.66 136.71 11.58 5,966,030.27 349,476.63 1.99 -115.27 MWD+IFR-AK-CAZ-SC(2) 1,506.57 17.49 28.05 1,490.44 1,419.44 160.44 23.09 5,966,053.77 349,488.62 3.03 -130.82 MWD+IFR-AK-CAZ-SC(2) 1,601.60 21.14 33.82 1,580.12 1,509.12 187.29 39.35 5,966,080.29 349,505.41 4.33 -146.90 MWD+IFR-AK-CAZ-SC(2) 1,694.39 24.51 40.27 1,665.64 1,594.64 215.89 61.11 5,966,108.44 349,527.74 4.52 -161.93 MWD+IFR-AK-CAZ-SC(2) 1,788.17 26.97 47.23 1,750.13 1,679.13 245.19 89.31 5,966,137.16 349,556.52 4.15 -174.56 MWD+IFR-AK-CAZ-SC(2) 1,882.93 29.89 50.21 1,833.46 1,762.46 274.90 123.23 5,966,166.18 349,591.03 3.43 -184.86 MWD+IFR-AK-CAZ-SC(2) 1,976.74 32.10 52.36 1,913.87 1,842.87 305.08 160.94 5,966,195.61 349,629.33 2.63 -193.82 MWD+IFR-AK-CAZ-SC(2) 2,071.48 34.09 55.30 1,993.24 1,922.24 335.58 202.71 5,966,225.25 349,671.69 2.70 -201.13 MWD+IFR-AK-CAZ-SC(2) 2,165.46 37.01 60.36 2,069.71 1,998.71 364.57 248.97 5,966,253.31 349,718.52 4.41 -205.01 MWD+IFR-AK-CAZ-SC(2) 2,233.29 37.32 61.67 2,123.77 2,052.77 384.42 284.81 5,966,272.44 349,754.75 1.25 -205.72 MWD+IFR-AK-CAZ-SC(2) 2,267.00 37.96 62.04 2,150.46 2,079.46 394.13 302.96 5,966,281.78 349,773.09 2.01 -205.77 MWD+IFR-AK-CAZ-SC' NOT an Actual Survey 10 3/4"x 13-1/2 2,321.66 38.99 62.63 2,193.25 2,122.25 409.92 333.08 5,966,296.96 349,803.52 2.01 -205.57 MWD+IFR-AK-CAZ-SC(3) 2,416.38 41.33 64.20 2,265.64 2,194.64 437.24 387.71 5,966,323.18 349,858.68 2.69 -204.04 MWD+IFR-AK-CAZ-SC(3) 2,511.56 43.80 66.43 2,335.74 2,264.74 464.09 446.21 5,966,348.85 349,917.71 3.04 -200.29 MWD+IFR-AK-CAZ-SC(3) 2,604.77 46.31 68.70 2,401.59 2,330.59 489.24 507.19 5,966,372.77 349,979.17 3.20 -193.86 MWD+IFR-AK-CAZ-SC(3) 2,699.24 49.00 70.31 2,465.22 2,394.22 513.66 572.59 5,966,395.87 350,045.04 3.11 -184.72 MWD+IFR-AK-CAZ-SC(3) 2,794.92 49.85 71.33 2,527.45 2,456.45 537.53 641.23 5,966,418.36 350,114.14 1.20 -173.57 MWD+IFR-AK-CAZ-SC(3) 2,888.60 49.90 71.50 2,587.82 2,516.82 560.36 709.12 5,966,439.82 350,182.48 0.15 -161.86 MWD+IFR-AK-CAZ-SC(3) 2,982.11 49.80 73.33 2,648.12 2,577.12 581.95 777.25 5,966,460.05 350,251.02 1.50 -148.94 MWD+IFR-AK-CAZ-SC(3) 3,076.74 49.97 70.94 2,709.10 2,638.10 604.15 846.12 5,966,480.86 350,320.32 1.94 -136.21 MWD+IFR-AK-CAZ-SC(3) 3,170.90 49.73 72.56 2,769.81 2,698.81 626.69 914.47 5,966,502.02 350,389.10 1.34 -124.02 MWD+IFR-AK-CAZ-SC(3) 3,265.24 49.72 71.99 2,830.80 2,759.80 648.61 983.03 5,966,522.55 350,458.08 0.46 -111.18 MWD+IFR-AK-CAZ-SC(3) 3,359.73 49.95 71.86 2,891.75 2,820.75 671.01 1,051.67 5,966,543.58 350,527.15 0.27 -98.74 MWD+IFR-AK-CAZ-SC(3) 3,453.39 49.75 71.77 2,952.14 2,881.14 693.35 1,119.69 5,966,564.55 350,595.59 0.23 -86.53 MWD+IFR-AK-CAZ-SC(3) 3,546.76 49.90 72.43 3,012.37 2,941.37 715.28 1,187.57 5,966,585.11 350,663.90 0.56 -74.02 MWD+IFR-AK-CAZ-SC(3) 3,641.22 49.75 74.33 3,073.31 3,002.31 735.92 1,256.73 5,966,604.36 350,733.45 1.55 -59.78 MWD+IFR-AK-CAZ-SC(3) 3,735.79 49.74 74.74 3,134.43 3,063.43 755.17 1,326.29 5,966,622.20 350,803.38 0.33 -44.12 MWD+IFR-AK-CAZ-SC(3) 3,829.64 49.91 74.89 3,194.97 3,123.97 773.95 1,395.49 5,966,639.59 350,872.94 0.22 -28.21 MWD+IFR-AK-CAZ-SC(3) 3,923.73 49.92 74.79 3,255.56 3,184.56 792.78 1,464.98 5,966,657.02 350,942.78 0.08 -12.22 MWD+IFR-AK-CAZ-SC(3) 4,017.51 49.68 73.43 3,316.09 3,245.09 812.39 1,533.86 5,966,675.24 351,012.04 1.14 2.81 MWD+IFR-AK-CAZ-SC(3) 4,112.34 49.76 72.59 3,377.40 3,306.40 833.52 1,603.05 5,966,694.99 351,081.64 0.68 16.63 MWD+IFR-AK-CAZ-SC(3) 4,204.12 49.61 70.91 3,436.78 3,365.78 855.44 1,669.51 5,966,715.57 351,148.51 1.41 28.48 MWD+IFR-AK-CAZ-SC(3) 4,298.05 49.84 68.99 3,497.51 3,426.51 880.01 1,736.82 5,966,738.78 351,216.30 1.58 38.39 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 8:40:40AM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference:'' actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,391.45 49.53 69.34 3,557.94 3,486.94 905.34 1,803.38 5,966,762.77 351,283.35 0.44 47.27 MWD+IFR-AK-CAZ-SC(3) 4,485.11 49.65 69.82 3,618.65 3,547.65 930.22 1,870.22 5,966,786.30 351,350.67 0.41 56.68 MWD+IFR-AK-CAZ-SC(3) 4,579.23 49.53 69.74 3,679.67 3,608.67 954.99 1,937.47 5,966,809.72 351,418.39 0.14 66.38 MWD+IFR-AK-CAZ-SC(3) 4,670.60 50.15 70.59 3,738.59 3,667.59 978.68 2,003.15 5,966,832.09 351,484.54 0.98 76.30 MWD+IFR-AK-CAZ-SC(3) 4,764.58 50.24 70.57 3,798.76 3,727.76 1,002.69 2,071.24 5,966,854.72 351,553.09 0.10 87.07 MWD+IFR-AK-CAZ-SC(3) 4,859.68 50.24 71.51 3,859.58 3,788.58 1,026.44 2,140.38 5,966,877.08 351,622.68 0.76 98.56 MWD+IFR-AK-CAZ-SC(3) 4,952.93 50.24 70.61 3,919.22 3,848.22 1,049.70 2,208.18 5,966,898.98 351,690.93 0.74 109.84 MWD+IFR-AK-CAZ-SC(3) 5,048.19 50.17 70.77 3,980.19 3,909.19 1,073.91 2,277.26 5,966,921.79 351,760.47 0.15 120.90 MWD+IFR-AK-CAZ-SC(3) 5,141.18 50.36 71.07 4,039.64 3,968.64 1,097.28 2,344.84 5,966,943.81 351,828.51 0.32 131.99 MWD+IFR-AK-CAZ-SC(3) 5,235.58 50.25 71.96 4,099.93 4,028.93 1,120.31 2,413.73 5,966,965.45 351,897.84 0.73 144.00 MWD+IFR-AK-CAZ-SC(3) 5,330.57 50.20 72.22 4,160.70 4,089.70 1,142.76 2,483.19 5,966,986.50 351,967.74 0.22 156.79 MWD+IFR-AK-CAZ-SC(3) 5,424.99 50.21 72.10 4,221.13 4,150.13 1,164.99 2,552.25 5,967,007.34 352,037.22 0.10 169.59 MWD+IFR-AK-CAZ-SC(3) 5,518.94 50.38 72.00 4,281.15 4,210.15 1,187.26 2,621.01 5,967,028.23 352,106.41 0.20 182.20 MWD+IFR-AK-CAZ-SC(3) 5,612.48 50.32 71.00 4,340.84 4,269.84 1,210.12 2,689.31 5,967,049.70 352,175.15 0.83 194.09 MWD+IFR-AK-CAZ-SC(3) 5,706.88 50.06 72.28 4,401.28 4,330.28 1,232.96 2,758.13 5,967,071.16 352,244.41 1.08 206.23 MWD+IFR-AK-CAZ-SC(3) 5,800.90 50.22 73.11 4,461.54 4,390.54 1,254.43 2,827.04 5,967,091.24 352,313.72 0.70 219.62 MWD+IFR-AK-CAZ-SC(3) 5,894.93 50.54 74.11 4,521.50 4,450.50 1,274.86 2,896.52 5,967,110.28 352,383.60 0.89 234.20 MWD+IFR-AK-CAZ-SC(3) 5,988.68 50.75 72.19 4,580.96 4,509.96 1,295.87 2,965.89 5,967,129.89 352,453.37 1.60 248.21 MWD+IFR-AK-CAZ-SC(3) 6,083.86 50.87 72.59 4,641.10 4,570.10 1,318.19 3,036.21 5,967,150.79 352,524.11 0.35 261.52 MWD+IFR-AK-CAZ-SC(3) 6,177.29 50.83 72.79 4,700.09 4,629.09 1,339.75 3,105.38 5,967,170.96 352,593.70 0.17 274.96 MWD+IFR-AK-CAZ-SC(3) 6,271.84 50.23 72.22 4,760.19 4,689.19 1,361.69 3,174.99 5,967,191.50 352,663.73 0.79 288.27 MWD+IFR-AK-CAZ-SC(3) 6,366.56 50.36 71.43 4,820.70 4,749.70 1,384.42 3,244.23 5,967,212.83 352,733.40 0.66 300.70 MWD+IFR-AK-CAZ-SC(3) 6,461.05 50.13 69.81 4,881.13 4,810.13 1,408.52 3,312.75 5,967,235.56 352,802.39 1.34 311.59 MWD+IFR-AK-CAZ-SC(3) 6,554.50 50.13 70.54 4,941.04 4,870.04 1,432.85 3,380.22 5,967,258.52 352,870.33 0.60 321.79 MWD+IFR-AK-CAZ-SC(3) 6,650.30 50.14 71.55 5,002.44 4,931.44 1,456.73 3,449.76 5,967,281.00 352,940.33 0.81 333.35 MWD+IFR-AK-CAZ-SC(3) 6,744.34 50.21 72.02 5,062.67 4,991.67 1,479.31 3,518.37 5,967,302.20 353,009.37 0.39 345.62 MWD+IFR-AK-CAZ-SC(3) 6,838.05 50.10 71.80 5,122.71 5,051.71 1,501.65 3,586.76 5,967,323.16 353,078.19 0.22 358.00 MWD+IFR-AK-CAZ-SC(3) 6,933.37 50.18 72.15 5,183,81 5,112.81 1,524.29 3,656.34 5,967,344.40 353,148.20 0.29 370.68 MWD+IFR-AK-CAZ-SC(3) 7,026.40 50.20 71.27 5,243.37 5,172.37 1,546.72 3,724.19 5,967,365.46 353,216.49 0.73 382.73 MWD+IFR-AK-CAZ-SC(3) 7,121.17 50.30 70.01 5,303.97 5,232.97 1,570.87 3,792.93 5,967,388.23 353,285.69 1.03 393.68 MWD+IFR-AK-CAZ-SC(3) 7,214.11 50.20 68.99 5,363.40 5,292.40 1,595.89 3,859.86 5,967,411.91 353,353.11 0.85 403.00 MWD+IFR-AK-CAZ-SC(3) 7,310.65 50.15 68.43 5,425.23 5,354.23 1,622.81 3,928.94 5,967,437.43 353,422.71 0.45 411.67 MWD+IFR-AK-CAZ-SC(3) 7,404.66 50.05 69.36 5,485.53 5,414.53 1,648.78 3,996.22 5,967,462.05 353,490.49 0.77 420.32 MWD+IFR-AK-CAZ-SC(3) 7,499.39 50.09 70.39 5,546.34 5,475.34 1,673.78 4,064.43 5,967,485.67 353,559.18 0.83 430.28 MWD+IFR-AK-CAZ-SC(3) 7,592.46 50.37 70.70 5,605.87 5,534.87 1,697.60 4,131.88 5,967,508.13 353,627.09 0.40 440.91 MWD+IFR-AK-CAZ-SC(3) 7,687.75 50.33 71.48 5,666.68 5,595.68 1,721.38 4,201.29 5,967,530.51 353,696.96 0.63 452.50 MWD+IFR-AK-CAZ-SC(3) 7,781.73 50.67 71.21 5,726.46 5,655.46 1,744.57 4,269.99 5,967,552.32 353,766.11 0.42 464.27 MWD+IFR-AK-CAZ-SC(3) 7,876.29 50.48 70.96 5,786.51 5,715.51 1,768.25 4,339.09 5,967,574.61 353,835.66 0.29 475.81 MWD+IFR-AK-CAZ-SC(3) 7,970.75 50.41 70.55 5,846.66 5,775.66 1,792.26 4,407.85 5,967,597.23 353,904.89 0.34 486.89 MWD+IFR-AK-CAZ-SC(3) 8,065.19 51.14 71.43 5,906.38 5,835.38 1,816.08 4,477.02 5,967,619.66 353,974.51 1.06 498.33 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 8:40:40AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,158.89 51.02 72.20 5,965.25 5,894.25 1,838.84 4,546.28 5,967,641.02 354,044.21 0.65 510.75 MWD+IFR-AK-CAZ-SC(3) 8,252.93 51.07 72.38 6,024.37 5,953.37 1,861.08 4,615.94 5,967,661.86 354,114.30 0.16 523.82 MWD+IFR-AK-CAZ-SC(3) 8,347.58 51.09 73.00 6,083.84 6,012.84 1,882.99 4,686.25 5,967,682.36 354,185.02 0.51 537.48 MWD+IFR-AK-CAZ-SC(3) 8,440.63 50.54 74.04 6,142.63 6,071.63 1,903.45 4,755.41 5,967,701.43 354,254.57 1.05 551.88 MWD+IFR-AK-CAZ-SC(3) 8,535.48 50.09 74.21 6,203.20 6,132.20 1,923.42 4,825.62 5,967,719.98 354,325.16 0.49 567.21 MWD+IFR-AK-CAZ-SC(3) 8,630.19 50.11 74.83 6,263.95 6,192.95 1,942.81 4,895.64 5,967,737.97 354,395.55 0.50 582.96 MWD+IFR-AK-CAZ-SC(3) 8,725.00 49.89 74.44 6,324.89 6,253.89 1,962.06 4,965.67 5,967,755.80 354,465.95 0.39 598.85 MWD+IFR-AK-CAZ-SC(3) 8,819.59 49.87 75.44 6,385.84 6,314.84 1,980.85 5,035.52 5,967,773.19 354,536.16 0.81 615.04 MWD+IFR-AK-CAZ-SC(3) 8,914.57 50.69 76.23 6,446.54 6,375.54 1,998.73 5,106.35 5,967,789.64 354,607.33 1.07 632.52 MWD+IFR-AK-CAZ-SC(3) 9,008.49 50.68 74.31 6,506.05 6,435.05 2,017.20 5,176.62 5,967,806.70 354,677.95 1.58 649.19 MWD+IFR-AK-CAZ-SC(3) 9,102.83 50.79 71.58 6,565.77 6,494.77 2,038.62 5,246.44 5,967,826.71 354,748.18 2.24 663.06 MWD+IFR-AK-CAZ-SC(3) 9,198.29 50.80 68.86 6,626.11 6,555.11 2,063.65 5,316.03 5,967,850.34 354,818.26 2.21 673.63 MWD+IFR-AK-CAZ-SC(3) 9,291.98 50.55 68.58 6,685.49 6,614.49 2,089.95 5,383.57 5,967,875.28 354,886.30 0.35 682.11 MWD+IFR-AK-CAZ-SC(3) 9,386.31 50.39 70.25 6,745.53 6,674.53 2,115.53 5,451.67 5,967,899.49 354,954.90 1.38 691.50 MWD+IFR-AK-CAZ-SC(3) 9,480.79 51.05 74.42 6,805.36 6,734.36 2,137.70 5,521.33 5,967,920.26 355,024.98 3.49 704.63 MWD+IFR-AK-CAZ-SC(3) 9,528.99 51.04 78.17 6,835.67 6,764.67 2,146.58 5,557.73 5,967,928.40 355,061.55 6.05 713.88 MWD+IFR-AK-CAZ-SC(3) 9,574.71 51.36 80.61 6,864.32 6,793.32 2,153.14 5,592.75 5,967,934.26 355,096.69 4.22 724.53 MWD+IFR-AK-CAZ-SC(3) 9,620.96 51.95 82.82 6,893.02 6,822.02 2,158.36 5,628.64 5,967,938.76 355,132.68 3.96 736.77 MWD+IFR-AK-CAZ-SC(3) 9,669.50 53.25 84.87 6,922.50 6,851.50 2,162.49 5,666.98 5,967,942.12 355,171.09 4.29 751.12 MWD+IFR-AK-CAZ-SC(3) 9,763.43 54.60 89.13 6,977.82 6,906.82 2,166.44 5,742.76 5,967,944.55 355,246.93 3.94 783.21 MWD+IFR-AK-CAZ-SC(3) 9,856.52 54.68 94.02 7,031.72 6,960.72 2,164.35 5,818.61 5,967,940.94 355,322.72 4.28 820.67 MWD+IFR-AK-CAZ-SC(3) 9,951.28 55.34 97.77 7,086.07 7,015.07 2,156.37 5,895.81 5,967,931.41 355,399.73 3.32 863.95 MWD+IFR-AK-CAZ-SC(3) 10,046.00 56.00 100.67 7,139.50 7,068.50 2,143.83 5,973.01 5,967,917.33 355,476.66 2.62 911.27 MWD+IFR-AK-CAZ-SC(3) 10,140.61 57.96 103.58 7,191.06 7,120.06 2,127.15 6,050.54 5,967,899.10 355,553.84 3.31 962.40 MWD+IFR-AK-CAZ-SC(3) 10,235.45 60.41 106.52 7,239.64 7,168.64 2,105.98 6,129.17 5,967,876.36 355,632.02 3.71 1,018.00 MWD+IFR-AK-CAZ-SC(3) 10,329.65 62.63 109.47 7,284.57 7,213.57 2,080.38 6,207.90 5,967,849.19 355,710.21 3.62 1,077.56 MWD+IFR-AK-CAZ-SC(3) 10,422.01 66.34 111.84 7,324.35 7,253.35 2,050.97 6,285.86 5,967,818.22 355,787.57 4.64 1,140.14 MWD+IFR-AK-CAZ-SC(3) 10,516.37 69.24 113.95 7,360.02 7,289.02 2,016.97 6,366.32 5,967,782.62 355,867.32 3.71 1,207.93 MWD+IFR-AK-CAZ-SC(3) 10,610.31 73.35 114.97 7,390.14 7,319.14 1,980.13 6,447.29 5,967,744.16 355,947.53 4.49 1,278.47 MWD+IFR-AK-CAZ-SC(3) 10,703.60 77.19 115.44 7,413.85 7,342.85 1,941.71 6,528.91 5,967,704.12 356,028.35 4.14 1,350.71 MWD+IFR-AK-CAZ-SC(3) 10,798.65 79.87 116.66 7,432.75 7,361.75 1,900.80 6,612.58 5,967,661.54 356,111.19 3.09 1,426.11 MWD+IFR-AK-CAZ-SC(3) 10,892.12 81.12 118.00 7,448.19 7,377.19 1,858.48 6,694.48 5,967,617.59 356,192.21 1.95 1,501.93 MWD+IFR-AK-CAZ-SC(3) 10,986.96 82.59 119.17 7,461.63 7,390.63 1,813.56 6,776.91 5,967,571.03 356,273.72 1.97 1,580.29 MWD+IFR-AK-CAZ-SC(3) 11,081.16 84.51 120.81 7,472.21 7,401.21 1,766.77 6,857.97 5,967,522.63 356,353.82 2.67 1,659.66 MWD+IFR-AK-CAZ-SC(3) 11,125.15 84.75 121.35 7,476.33 7,405.33 1,744.16 6,895.48 5,967,499.28 356,390.87 1.34 1,697.23 MWD+IFR-AK-CAZ-SC(3) 11,176.80 86.42 122.77 7,480.30 7,409.30 1,716.83 6,939.12 5,967,471.08 356,433.95 4.24 1,741.85 MWD+IFR-AK-CAZ-SG"` NOT an Actual Survey 7-5/8"x 9-7/8" 11,219.18 87.79 123.93 7,482.44 7,411.44 1,693.56 6,974.48 5,967,447.11 356,468.83 4.24 1,778.99 MWD+IFR-AK-CAZ-SC(4) 11,315.42 88.69 126.50 7,485.40 7,414.40 1,638.10 7,053.06 5,967,390.08 356,546.28 2.83 1,864.86 MWD+IFR-AK-CAZ-SC(4) 11,411.53 89.55 129.95 7,486.88 7,415.88 1,578.64 7,128.54 5,967,329.13 356,620.54 3.70 1,952.79 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 8:40:40AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 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 11,459.09 89.71 132.83 7,487.18 7,416.18 1,547.20 7,164.22 5,967,296.98 356,655.58 6.06 1,997.30 MWD+IFR-AK-CAZ-SC(4) 11,504.67 90.34 136.47 7,487.16 7,416.16 1,515.18 7,196.64 5,967,264.32 356,687.35 8.10 2,040.80 MWD+IFR-AK-CAZ-SC(4) 11,554.31 89.34 139.42 7,487.30 7,416.30 1,478.32 7,229.89 5,967,226.81 356,719.85 6.27 2,088.94 MWD+IFR-AK-CAZ-SC(4) 11,600.60 90.23 141.69 7,487.48 7,416.48 1,442.58 7,259.29 5,967,190.48 356,748.53 5.27 2,134.31 MWD+IFR-AK-CAZ-SC(4) 11,696.04 90.03 143.62 7,487.26 7,416.26 1,366.71 7,317.19 5,967,113.47 356,804.89 2.03 2,228.48 MWD+IFR-AK-CAZ-SC(4) 11,791.92 89.89 146.70 7,487.33 7,416.33 1,288.02 7,371.95 5,967,033.71 356,858.06 3.22 2,323.67 MWD+IFR-AK-CAZ-SC(4) 11,887.57 90.27 150.03 7,487.19 7,416.19 1,206.60 7,422.12 5,966,951.30 356,906.58 3.50 2,419.11 MWD+IFR-AK-CAZ-SC(4) 11,982.10 90.00 154.27 7,486.97 7,415.97 1,123.04 7,466.27 5,966,866.88 356,949.04 4.49 2,513.62 MWD+IFR-AK-CAZ-SC(4) 12,077.59 90.37 155.68 7,486.66 7,415.66 1,036.51 7,506.66 5,966,779.57 356,987.69 1.53 2,608.98 MWD+IFR-AK-CAZ-SC(4) 12,173.12 90.56 154.55 7,485.89 7,414.89 949.86 7,546.86 5,966,692.13 357,026.14 1.20 2,704.36 MWD+IFR-AK-CAZ-SC(4) 12,268.08 89.71 154.72 7,485.66 7,414.66 864.05 7,587.53 5,966,605.54 357,065.08 0.91 2,799.22 MWD+IFR-AK-CAZ-SC(4) 12,363.92 89.86 154.69 7,486.02 7,415.02 777.40 7,628.48 5,966,518.09 357,104.29 0.16 2,894.95 MWD+I F R-AK-CAZ-SC(4) 12,459.34 89.41 154.35 7,486.63 7,415.63 691.27 7,669.53 5,966,431.15 357,143.60 0.59 2,990.28 MWD+IFR-AK-CAZ-SC(4) 12,554.74 89.11 155.88 7,487.86 7,416.86 604.73 7,709.67 5,966,343.84 357,181.99 1.63 3,085.52 MWD+IFR-AK-CAZ-SC(4) 12,650.39 88.93 155.18 7,489.50 7,418.50 517.69 7,749.29 5,966,256.02 357,219.85 0.76 3,180.98 MWD+IFR-AK-CAZ-SC(4) 12,745.68 89.45 156.75 7,490.85 7,419.85 430.67 7,788.09 5,966,168.25 357,256.90 1.74 3,276.03 MWD+IFR-AK-CAZ-SC(4) 12,840.55 89.77 156.28 7,491.49 7,420.49 343.66 7,825.90 5,966,080.51 357,292.95 0.60 3,370.60 MWD+IFR-AK-CAZ-SC(4) 12,936.09 89.13 157.80 7,492.41 7,421.41 255.70 7,863.16 5,965,991.82 357,328.44 1.73 3,465.76 MWD+IFR-AK-CAZ-SC(4) 13,031.28 89.38 156.49 7,493.65 7,422.65 167.99 7,900.13 5,965,903.40 357,363.64 1.40 3,560.56 MWD+IFR-AK-CAZ-SC(4) 13,126.49 89.45 156.43 7,494.62 7,423.62 80.71 7,938.15 5,965,815.38 357,399.90 0.10 3,655.48 MWD+IFR-AK-CAZ-SC(4) 13,221.98 88.93 156.35 7,495.97 7,424.97 -6.78 7,976.40 5,965,727.15 357,436.38 0.55 3,750.68 MWD+IFR-AK-CAZ-SC(4) 13,317.60 88.83 156.23 7,497.84 7,426.84 -94.31 8,014.84 5,965,638.87 357,473.06 0.16 3,846.01 MWD+IFR-AK-CAZ-SC(4) 13,412.85 88.80 155.70 7,499.81 7,428.81 -181.28 8,053.62 5,965,551.14 357,510.09 0.56 3,941.01 MWD+IFR-AK-CAZ-SC(4) 13,508.02 88.97 153.90 7,501.66 7,430.66 -267.38 8,094.14 5,965,464.26 357,548.86 1.90 4,036.05 MWD+IFR-AK-CAZ-SC(4) 13,603.36 89.76 154.02 7,502.72 7,431.72 -353.03 8,135.99 5,965,377.79 357,588.99 0.84 4,131.32 MWD+IFR-AK-CAZ-SC(4) 13,699.04 89.86 152.91 7,503.03 7,432.03 -438.63 8,178.73 5,965,291.36 357,630.00 1.16 4,226.97 MWD+IFR-AK-CAZ-SC(4) 13,794.68 89.86 152.40 7,503.27 7,432.27 -523.58 8,222.66 5,965,205.55 357,672.22 0.53 4,322.60 MWD+IFR-AK-CAZ-SC(4) 13,889.71 89.89 151.37 7,503.47 7,432.47 -607.40 8,267.44 5,965,120.86 357,715.31 1.08 4,417.63 MWD+IFR-AK-CAZ-SC(4) 13,984.40 89.89 150.19 7,503.66 7,432.66 -690.04 8,313.67 5,965,037.32 357,759.86 1.25 4,512.30 MWD+IFR-AK-CAZ-SC(4) 14,080.39 89.83 149.80 7,503.89 7,432.89 -773.16 8,361.67 5,964,953.25 357,806.18 0.41 4,608.23 MWD+IFR-AK-CAZ-SC(4) 14,176.50 89.69 151.09 7,504.29 7,433.29 -856.76 8,409.08 5,964,868.72 357,851.90 1.35 4,704.30 MWD+IFR-AK-CAZ-SC(4) 14,271.15 89.89 151.19 7,504.64 7,433.64 -939.66 8,454.76 5,964,784.93 357,895.91 0.24 4,798.94 MWD+IFR-AK-CAZ-SC(4) 14,366.62 89.76 151.30 7,504.93 7,433.93 -1,023.36 8,500.69 5,964,700.34 357,940.15 0.18 4,894.40 MWD+IFR-AK-CAZ-SC(4) 14,457.83 89.76 150.44 7,505.31 7,434.31 -1,103.03 8,545.09 5,964,619.80 357,982.94 0.94 4,985.59 MWD+IFR-AK-CAZ-SC(4) 14,549.27 90.07 150.56 7,505.45 7,434.45 -1,182.61 8,590.11 5,964,539.33 358,026.36 0.36 5,077.00 MWD+IFR-AK-CAZ-SC(4) 14,641.74 90.00 151.42 7,505.39 7,434.39 -1,263.48 8,634.96 5,964,457.59 358,069.57 0.93 5,169.45 MWD+IFR-AK-CAZ-SC(4) 14,733.58 89.41 149.48 7,505.87 7,434.87 -1,343.37 8,680.25 5,964,376.82 358,113.24 2.21 5,261.25 MWD+IFR-AK-CAZ-SC(4) 14,825.32 88.54 150.17 7,507.51 7,436.51 -1,422.66 8,726.35 5,964,296.62 358,157.75 1.21 5,352.91 MWD+IFR-AK-CAZ-SC(4) 14,915.80 88.87 150.43 7,509.55 7,438.55 -1,501.24 8,771.17 5,964,217.17 358,200.98 0.46 5,443.33 MWD+IFR-AK-CAZ-SC(4) 15,007.77 88.58 149.78 7,511.60 7,440.60 -1,580.95 8,817.00 5,964,136.56 358,245.19 0.77 5,535.23 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 8:40:40AM Page 6 COMPASS 5000.1 Build 74 • i Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-05 Project: Western North Slope TVD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: actual:34.3+36.7 @ 71.00usft(Doyon 19) Well: CD5-05 !'North Reference: True Wellbore: CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05 Database: OAKEDMP2 rm Survey Map Map Verticals MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 15,099.35 89.17 149.78 7,513.40 7,442.40 -1,660.07 8,863.08 5,964,056.54 358,289.68 0.64 5,626.72 MWD+IFR-AK-CAZ-SC(4) 15,191.66 89.62 150.95 7,514.37 7,443.37 -1,740.30 8,908.72 5,963,975.42 358,333.70 1.36 5,718.98 MWD+IFR-AK-CAZ-SC(4) 15,283.15 89.62 150.40 7,514.98 7,443.98 -1,820.06 8,953.53 5,963,894.78 358,376.89 0.60 5,810.45 MWD+IFR-AK-CAZ-SC(4) 15,375.61 89.72 150.61 7,515.51 7,444.51 -1,900.54 8,999.05 5,963,813.41 358,420.79 0.25 5,902.87 MWD+IFR-AK-CAZ-SC(4) 15,466.93 89.79 153.74 7,515.90 7,444.90 -1,981.29 9,041.67 5,963,731.83 358,461.78 3.43 5,994.18 MWD+IFR-AK-CAZ-SC(4) 15,559.67 89.79 152.33 7,516.24 7,445.24 -2,063.94 9,083.72 5,963,648.35 358,502.16 1.52 6,086.90 MWD+IFR-AK-CAZ-SC(4) 15,651.76 89.65 152.17 7,516.69 7,445.69 -2,145.44 9,126.60 5,963,566.02 358,543.39 0.23 6,178.99 MWD+IFR-AK-CAZ-SC(4) 15,742.62 89.52 152.29 7,517.35 7,446.35 -2,225.83 9,168.93 5,963,484.80 358,584.10 0.19 6,269.85 MWD+IFR-AK-CAZ-SC(4) 15,837.33 89.45 151.07 7,518.20 7,447.20 -2,309.20 9,213.86 5,963,400.55 358,627.35 1.29 6,364.55 MWD+IFR-AK-CAZ-SC(4) 15,933.70 89.79 151.82 7,518.84 7,447.84 -2,393.85 9,259.93 5,963,315.00 358,671.70 0.85 6,460.91 MWD+IFR-AK-CAZ-SC(4) 16,027.86 89.55 152.76 7,519.38 7,448.38 -2,477.21 9,303.71 5,963,230.79 358,713.80 1.03 6,555.07 MWD+IFR-AK-CAZ-SC(4) 16,123.37 89.83 152.04 7,519.90 7,448.90 -2,561.85 9,347.96 5,963,145.29 358,756.34 0.81 6,650.58 MWD+IFR-AK-CAZ-SC(4) 16,220.01 89.72 151.70 7,520.28 7,449.28 -2,647.07 9,393.52 5,963,059.17 358,800.18 0.37 6,747.21 MWD+IFR-AK-CAZ-SC(4) 16,313.91 89.76 150.82 7,520.70 7,449.70 -2,729.40 9,438.67 5,962,975.96 358,843.67 0.94 6,841.10 MWD+IFR-AK-CAZ-SC(4) 16,409.32 89.65 151.57 7,521.19 7,450.19 -2,813.00 9,484.64 5,962,891.46 358,887.95 0.79 6,936.50 MWD+IFR-AK-CAZ-SC(4) 16,505.06 89.55 150.92 7,521.86 7,450.86 -2,896.93 9,530.70 5,962,806.63 358,932.31 0.69 7,032.23 MVVD+IFR-AK-CAZ-SC(4) 16,600.43 89.04 150.51 7,523.04 7,452.04 -2,980.11 9,577.34 5,962,722.54 358,977.28 0.69 7,127.57 MWD+IFR-AK-CAZ-SC(4) 16,695.74 88.73 149.56 7,524.89 7,453.89 -3,062.66 9,624.94 5,962,639.06 359,023.20 1.05 7,222.80 MWD+IFR-AK-CAZ-SC(4) 16,790.46 88.63 149.55 7,527.07 7,456.07 -3,144.30 9,672.92 5,962,556.48 359,069.54 0.11 7,317.41 MWD+IFR-AK-CAZ-SC(4) 16,886.40 88.80 148.71 7,529.22 7,458.22 -3,226.63 9,722.13 5,962,473.19 359,117.09 0.89 7,413.21 MWD+IFR-AK-CAZ-SC(4) 16,982.23 89.35 149.64 7,530.77 7,459.77 -3,308.91 9,771.23 5,962,389.95 359,164.52 1.13 7,508.91 MWD+IFR-AK-CAZ-SC(4) 17,080.35 89.93 149.61 7,531.39 7,460.39 -3,393.56 9,820.85 5,962,304.32 359,212.42 0.59 7,606.94 MWD+IFR-AK-CAZ-SC(4) 17,173.11 90.03 149.06 7,531.42 7,460.42 -3,473.35 9,868.15 5,962,223.61 359,258.12 0.60 7,699.60 MWD+IFR-AK-CAZ-SC(4) 17,269.19 90.37 149.57 7,531.09 7,460.09 -3,555.97 9,917.19 5,962,140.02 359,305.48 0.64 7,795.57 MWD+IFR-AK-CAZ-SC(4) 17,363.32 90.51 148.86 7,530.36 7,459.36 -3,636.84 9,965.36 5,962,058.22 359,352.02 0.77 7,889.59 MWD+IFR-AK-CAZ-SC(4) 17,458.41 90.07 148.62 7,529.88 7,458.88 -3,718.12 10,014.70 5,961,975.96 359,399.72 0.53 7,984.52 MWD+IFR-AK-CAZ-SC(4) 17,888.00 90.07 148.62 7,529.36 7,458.36 -4,084.87 10,238.40 5,961,604.83 359,616.00 0.00 8,413.37 NOT an Actual Survey 4 112"x 6-1/2" 17,900.00 90.07 148.62 7,529.34 7,458.34 -4,095.12 10,244.65 5,961,594.46 359,622.04 0.00 8,425.35 BLIND Surveys to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. (] Yes ❑ No 1 have checked to the best of my ability that the following data is correct: rn Surface Coordinates Declination & Convergence Survey Tool Codes Vincent SLB DE: Osara Mar.101^;3°s wsb WOW Digitally sspned by john.4samuelfeconowPhaps.com Client Representative: John.g.samuell@conocophlllips.com czo;sa�i,�ne novo llhps.corn Date: 23-Sep-2015 9/24/2015 8:40:40AM Page 7 COMPASS 5000.1 Build 74 i • if, Cement Detail Report + . CD5-05 Conocc)Phillips String: Surface Casing Cement Job: DRILLING ORIGINAL,8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/15/2015 15:23 8/16/2015 01:02 CD5-05 Comment Pump 100.1 bbl of 10.5 ppg MudPush II at 4.8-5.2 BPM, 120-210 psi. Unsting from Volant tool, insert bottom cement plug, sting in with Volant tool. Pump 471.1 bbl of 11.0 LiteCRETE Lead cement plus additives at 5.7 to 7.1 BPM,290-330 psi. Reciprocate pipe 6-8'throughout. Note: Had cement returns to surface after 450 bbl of Lead was pumped. Cement returns to surface after displacement was 275 bbl. Pump 60.1 bbl of 15.8 ppg"G"Tail cement at 2.7 bbl,while reciprocating pipe(PU= 195K, SO= 107K). Slowed pump rate due to pump jacking and cement line whipping in derrick. Casing string stuck 8'high while reciprocating,after 44 bbl of Tail cmt pumped.Continue pumping remaining cmt with returns to surface. (00:10 hrs). Shut down cement pump, un-sting Volant tool from casing and insert top cement plug. Sting in with Volant tool and pump 20.1 bbl of water with cement pump and shut down. Displace with rig pump at 3-6 BPM,430-680 psi. Had partial returns during first 40 bbl pumped increasing to full returns.Slowed pumps to 3 BPM,430-450 psi for last 40 bbl of displacement. Bumped plug as calculated at 189.8 bbl pumped. Increase pressure to 940 psi and held for 5 min. (Worked pipe throughout displacement with 50-325K Ib,but no movement). Bled pressure and floats were not holding. Applied surface pressure,reseated plugs and held 940 psi on floats while WOC. Note:CIP at 01:02 hrs 8/16/15 Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,267.0 Yes 275.0 Yes Yes Q Pump nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 2 6 572.0 450.0 Yes 7.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.7 1,780.0 1,250 DeepCRETE 471.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.93 6.97 0.00 11.00 0.00 50.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOW Additive Type Concentration Conc Unit label Dispersant D185 0.08 gal/sx Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D500 1.0 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,780.0 2,267.0 285 G 63.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control S002 0.6 %BWOC Page 1/1 Report Printed: 9/30/2015 • w Cement Detail Report CD5-05 virr ComcoPhillips String: Intermediate Stage 1 Job: DRILLING ORIGINAL, 8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Stage 1 8/27/2015 02:19 8/27/2015 00:00 CD5-05 Comment PJSM on cementing. Dowell pump 3 bbls H2O and pressure test lines to 4,000 psi(good),42.3 bbls 12.0 ppg Mud Push, un-sting Volant tool and insert bypass plug,sting in, pump 93 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement(40%inxs), un-sting Volant tool,drop top plug. Dowell displace w/10.1 bbls H20. Rig displace w/493 4 bbls 11.1 ppg LSND at 7.1 bpm,slowing to 3 bpm for final 20 bbl of displacement. Full returns at surface while pumping but not pipe reciprocation. Bump plug,increase pressure to 930 psi(500 psi over)and held for 5 min. Bleed pressure and check floats-not holding. Trap casing pressure, check valve alignment and recheck floats-not holding. Re-bump plug and increase pressure to 910 psi and shut-in. CIP @ 03:36 hrs -1st stage cement job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Stage 1 Cement 500'above 10,152.0 11,177.0 Yes Yes Yes Alpine A Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 992.0 747.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(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: 9/30/2015 • • Cement Detail Report CD5-05 Coriocc*hitlips String: Intermediate Stage 2 Job: DRILLING ORIGINAL, 8/12/2015 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Stage 2 8/27/2015 14:14 8/27/2015 14:31 CD5-05 Comment PJSM. Cementers fill lines with water and test to 4,000 psi. pump 41 bbls 12.0 ppg Mud Push, 91 bbls of 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement+ additives(40%inxs). Drop closing plug and cementers displace w/10 bbls H20. Rig displace w/261 bbls of 11.1 ppg LSND,at 7-3 bpm,600-380 psi. Plug would not bump,stop and cycle pump up and down and plug finally bumped at 1,700 psi,to close stage collar. (Full returns during displacement). Bled pressure and check if stage collar holding. Flow back observed. Pressure back up to 2,200 psi and pressure bled to 1,680 psi in 15 min. Pressure up to 3,150psi and held for 10minutes then 3,600 psi and hold for 10 minutes. Bleed pressure and check for flow-static,no flow. Cement Stages Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Stage 2 4,600.0 5,631.0 Yes 0.0 Yes No Q Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 5 6 737.0 737.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 5,632.0 Drill Bit 5,634.0 6 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,152.0 10,177.0 430 G Yield ye/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/30/2015 • • Bettis, Patricia K (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, September 02, 2015 10:47 AM To: Earhart, Will C Cc: Bettis, Patricia K (DOA) Subject: RE: CRU CD5-05 (PTD 215-073)- MWD Failure- Request to Drill Ahead Will, Approval is granted to drill ahead up to 700'without MWD data as described below. 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.Loepp aC7.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Earhart, Will C [mailto:William.C.Earhart@conocophillips.com] Sent: Wednesday, September 02, 2015 10:41 AM To: Loepp, Victoria T(DOA) Cc: Stinson, Rob D Subject: CRU CD5-05 (PTD 215-073)- MWD Failure- Request to Drill Ahead Victoria, Per your verbal approval,we will drill ahead <700ft measured depth without MWD data on CRU CD5-05(215-073). Due to a MWD tool failure, communication from downhole tools ceased at 17,571' MD within the Alpine A reservoir. The intermediate casing shoe is set at 11,175' MD. At the time of the failure -6400ft of horizontal section had been drilled. Given that we saw little to no build or walk tendencies from the BHA, we are confident in our ability to very predictably drill forward towards planned TD. We are currently 5ft from the interpreted top of the Alpine A reservoir so given the predictability of the BHA to this point we are comfortable that we will stay within zone. In the rare chance we exit the Alpine A,given the competency of the Alpine B formation above us we see little to no incremental risk in this excursion. Thank you for your support on this issue. -Will 1 i 0 Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart uaconocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 2 • Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Tuesday,August 11, 2015 11:39 AM To: Loepp,Victoria T (DOA) Subject: RE:CRU CD5-05 (PTD 215-073) Surface Casing Point Revision Attachments: CD5 Amended Cement Calcs.docx;2.CD5-05 10-401_Amended.xls Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for your response. Please let me know if you need any additional information beyond what is below. Surface Casing set depth: 2,267' MD/2,161'TVD 10.75" Surface Casing run to 2,267' MD/2,161' TVD Cement from 2267' MD to 1767' (500' of tail)with Class G+Adds. @ 15.8 PPG, and from 1767'to surface with 11.0 ppg Arctic Lite Crete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1330' MD), zero excess in 20"conductor. Lead slurry from 1,767'MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (110'—0') X 1.3645 ft/ft X 1.0(0%excess) =150 ft3 Permafrost to Conductor (1,330'—110') X 0.3637 ft3/ft X 3.5(250%excess)=1,553 ft3 Top of Tail to Permafrost (1,767'—1,330')X 0.3637 ft3/ft X 1.5(50%excess) =239 ft3 Total Volume=150+1,553+239= 1,942 ft3=>1,007 sx of 11.0 ppg Arctic Lite Crete @ 1.93 ft3/sk Tail slurry from 2,267'MD to 1,767'MD with 15.8 ppg Class G+additives Shoe to Top of Tail (2,267'—1,767')X 0.3637 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=>273 sx of 15.8 ppg Class G+0.2%D046 antifoamer,0.3%D065 dispersant and 0.8%S002 accelerator @ 1.16 ft3/sk Thanks Will 1 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMARION PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑✓ Service- Winj ❑ Single Zone Q 1 c.Specify if well is proposed for: Drill Q Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 2 Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 CRU CD5-05 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 18307 TVD: 7542 Colville River Unit 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Alpine Pool Surface: 316'FNL,2517' FEL,Sec.18,T11N,R4E,UM ASRC NPR4,ASRC NPR2,ADL387208 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3904'FNL,756'FEL,Sec.8,T11N,R4E,UM 932128,932671,932193 5/5/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4797'FNL,2749'FEL,Sec.16,T11N,R4E,UM 15912,12614.53,1145.67 2490'to ADL 380075 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 70.3 feet 15.Distance to Nearest Well Open Surface: x- 349462 y- 5965894 Zone- 4 GL Elevation above I 34 feet to Same Pool: 1600' 16.Deviated wells: Kickoff depth: 534 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3,256 Surface: 2,511 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 20" 94 L-80 Welded 80 30 36 110 110 6 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2231 36 36 2267 2161 1,007 sx 11.0 ppg G,273 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 11241 36 36 11277 7453 260 sx 15.8 ppg G 6-3/4" 4-1/2" 12.6 L-80 IBTM 7207 11100 7434 18307 7542 n/a 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 4/17/2015 22. I hereby certify that the foregoing is true and correct. Will Earhart- 265-1077 Contact Email WIIIiam.C.EarhartCa�cop.com Printed Name Title Drilling Manager Signature Phone 265-6120 Date 4/17/2015 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd:Yes❑ No❑ H2S measures: Yes 0 No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • CD5-05 Amended Surface Casing Set Point Cement Calculations 10.75"Surface Casing run to 2,267'MD/2,161'TVD Cement from 2267' MD to 1767'(500' of tail)with Class G+Adds.@ 15.8 PPG,and from 1767'to surface with 11.0 ppg Arctic Lite Crete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1330' MD),zero excess in 20"conductor. Lead slurry from 1,767'MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (110'—0') X 1.3645 ft3/ft X 1.0(0%excess) = 150 ft3 Permafrost to Conductor (1,330'— 110') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,553 ft3 Top of Tail to Permafrost (1,767'— 1,330')X 0.3637 ft3/ft X 1.5(50%excess) = 239 ft3 Total Volume= 150+ 1,553 + 239 = 1,942 ft3=> 1,007 sx of 11.0 ppg Arctic Lite Crete @ 1.93 ft3 /sk Tail slurry from 2,267'MD to 1,767'MD with 15.8 ppg Class G +additives Shoe to Top of Tail (2,267'—1,767')X 0.3637 ft3/ft X 1.50(50%excess) = 273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume = 273 +43 = 316 ft3 => 273 sx of 15.8 ppg Class G +0.2%D046 antifoamer, 0.3% D065 dispersant and 0.8%5002 accelerator @ 1.16 ft3/sk • Will Earhart • • Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Tuesday, August 11, 2015 9:45 AM To: Earhart, Will C Subject: [EXTERNAL]RE: CRU CD5-05 (PTD 215-073) Surface Casing Point Revision Will, This modification to the Surface Casing Point is approved. Please include this email approval with your approved PTD. Please send the revised cement volumes and revised casing setting depth via email. Thanx, Victoria From: Earhart, Will C [mailto:William.C.Earhart@iconocophillips.com] Sent: Friday, August 07, 2015 9:23 AM To: Loepp, Victoria T(DOA) Subject: CRU CD5-05 (PTD 215-073) Surface Casing Point Victoria, In regards to well CRU CD5-05 (PTD 215-073),we would like to move the surface casing shoe shallower than anticipated on the approved PTD. We would let to now set it at 160ft TVD above the prognosed C-30 sand rather than the previous 30ft TVD above the sand.This will be a difference of—200ft MD shallower. This is the same action taken on the well we are currently drilling-CRU CD5-313 and is the result of lower than anticipated surface casing shoe leak-off values seen on the first two surface casing set on the new pad—CRU CD5-314 and CD5-04. We still intend to operate with the diverter in service during the surface section operations as described in the approved PTD. Would you like me to submit a revised 10-401 highlighting the changes casing setting depth and resulting change in cementing volumes? Please let me know if you have any feedback or concerns. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 2 • • PTS z/ o 7-3 Loepp, Victoria T (DOA) From: Earhart, Will C <William.C.Earhart@conocophillips.com> Sent: Wednesday,July 29, 2015 3:27 PM To: Bettis, Patricia K(DOA); Loepp, Victoria T (DOA) Subject: RE: CRU CD5-05 (PTD 215-073) Follow Up Flag: Follow up Flag Status: Flagged Thank you for your support Patricia. The full suite of logs as outlined was indeed collected on CD5-313 from surface to the pilot hole TD. We will proceed with our plan to omit the resistivity tool. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earharta(�conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 From: Bettis, Patricia K (DOA) [rnailto:patricia.bettis@alaska.gov] Sent: Wednesday, July 29, 2015 3:12 PM To: Earhart, Will C; Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: CRU CD5-05 (PTD 215-073) Will, The AOGCC is amenable if ConocoPhillips has and/or is planning to run a full suite of logs, including neutron,density and mud log,from base of conductor to total depth in the CD5-313 pilot hole, as per my email dated 5/15/2015. Thank you, Patricia From: Earhart,Will C [mailto:William.C.Earhart@conocophillips.com] Sent:Tuesday,July 28, 2015 2:39 PM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>; Loepp, Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:CRU CD5-05 (PTD 215-073) Patricia/Victoria, Looking ahead to our next well at Alpine-CRU CD5-05 (PTD 215-073)-we would like to change our 13.5" surface hole drilling BHA by omitting the resistivity tool that I listed in the PTD. As this will now be our 4"surface hole penetration at the new CD5 well,we do not foresee the value in additional shallow resistivity data on the pad.As comparison,this would return us to the same surface hole logging deliverables 1 • • used at CD4 last year.We will still run the directional MWD and gamma ray as indicated in the PTD. Furthermore, we will still run gamma and resistivity in the intermediate and production sections as planned- no changes there. Please let me know if you approve this change to the approved PTD. -Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 2 • • Bettis, Patricia K (DOA) ?%i 2/5 —o? From: Bettis, Patricia K(DOA) Sent: Friday, May 15, 2015 9:33 AM To: 'Knock, Douglas G'; Dai,Weifeng (Weifeng.Dai@conocophillips.com) Cc: Loepp,Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: CD5-313 Development Well Doug, Thank you for meeting with us on May 14, 2015 to discuss the CD5-314 well. The AOGCC understands that ConocoPhillips plans to drill the CD5-313 well immediately after the CD5-04 well. The CD5- 04 is expected to spud early the week of May le and take approximately 35 days to drill. The CD5-313 will be the replacement well for the CD5-314 which was suspended after encountering shallow water flow between 400-530'. ConocoPhillips plans to run a full suite of logs, including neutron, density and mud log,from base of conductor to total depth in the CD5-313 pilot hole. With this understanding, recording of the neutron-density logs within the surface and intermediate holes for CD5-04 and CD5-05 is not required. Running a mud log within CD5-04 and CD5-05 also is not required. Please submit the permit to drill application for CD5-313 as soon as possible. As discussed in the meeting, if CD5-313 is not drilled,the AOGCC will required recording of the neutron, density, mud logs within the CD5-05 well. 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 1 ,i,, OF T • 1 �w���\I%%%sem THE STATE Alaska Oil and Gas 1�111 �� Ofl�TJASKA Conservation Commission i;E-1T-e _ 333 West Seventh Avenue u : GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Th.' ' Main: 907.279.1433 G''''41:11°..' Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, Alpine Oil Pool, CRU CD5-05 ConocoPhillips Alaska, Inc. Permit No: 215-073 Surface Location: 316' FNL, 2517' FEL, Sec. 18, T11N, R4E, UM Bottomhole Location: 4797' FNL, 2749' FEL, Sec. 16, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 1-6-1 Cathy P. oerster Chair DATED this day of May, 2015. STATE OF ALASKA RECEIVED ALL:A OIL AND GAS CONSERVATION COMNISDN APR 1 7 2015 PERMIT TO DRILL 20 AAC 25.005 kOG GO la.Type of Work: lb. Proposed Well Class: Development-Oil CI , Service- Winj ❑ Single Zone ❑✓ ‘ 1c.Specify if well is proposed for: Drill E, Lateral ❑ Stratigraphic Test ❑ Development-Gas❑' Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory ❑ Service- WAG E Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑, Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , CRU CD5-05 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 18307 ' TVD: ' 7542 Colville River Unit 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Alpine Pool • Surface: 316'FNL,2517' FEL,Sec. 18,T11N, R4E,UM , ASRC NPR4,ASRC NPR2,ADL387208 . Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 3904'FNL,756'FEL,Sec.8,T11N, R4E, UM . 932128,932671,932193 5/5/2015 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 4797'FNL,2749'FEL,Sec. 16,T11N, R4E, UM • 15912, 12614.53, 1145.67 . 2490'to ADL 380075 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above I • 70.3 feet 15. Distance to Nearest Well Open Surface: x- 349462 y- 5965894 Zone- 4 GL Elevation above I . 34 feet to Same Pool: 1600' 16.Deviated wells: Kickoff depth: • 534 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 90 degrees Downhole: 3,256. Surface: 2,511 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94 L-80 Welded 80 30 36 110 110 6 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2468 36 36 2504 2350 1,173 sx 11.2 ppg G,273 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 11241 36 36 11277 7453 260 sx 15.8 ppg G 6-3/4" 4-1/2" 12.6 L-80 IBTM 7207 11100 7434 18307 7542 n/a 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis II Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 4/17/2015 22. I hereby certify that the foregoing is true and correct. Will Earhart- 265-1077 Contact Email William.C.Earhart(c�cop.com Printed Nameardt.4....4.... L /lrN Title Drilling Manager Signature / it/C L- a4 Phone 265-6120 Date 4/17/2015 ` Commission Use Only Permit to Dril > API Number: Permit Approval See cover letter for other Number: S, - 6 T-:_3 50- 103-ao7-j( -QQ- OO Date: .5-/'{(2c,(rj, requirements. • Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Et„ Other: 43Q,fJ f C„1 f to c35 O d /P S 1 ' Samples req'd: Yes ❑ No12 Mud log req'd:Yes❑_No G rln lar TJ i'�V l/ 7! ✓ fts f .25- 01,5i. HZS measures: Yes ❑ No❑ Directional svy req'd:Yes❑ No❑�. V Spacing exception req'd: Yes ❑ No El Inclination-only svy req'd:Yes❑ No Q APPROVED BY Approved by' P /� GR4 �it/--//''�� COMMISSIONEROTHE COMMISSION Date:S- ¢-i.5 U TL 4 34//c �� A �) I/Z�,� Submit Form and Form 10-401(Revised 10/2012) t s i7A nths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • ConocoPhillips Alaska,Inc. • Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 April 17,2015 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 APR 172015 Re: Application for Permit to Drill CRU CD5-05 Q r Dear Sir or Madam: • `OG"C ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD5 drilling pad with rig Doyon 19.eThe intended spud date for this well is 6/1/15.However,in the event the present well being drilled by Doyon 19 (CRU CD5-314)finds unsatisfactory results in its pilot hole,it would be desired to move the rig onto to CD5-05 as early as 5/5/15. CRU CD5-05 is planned to be Alpine A sand producer. The 13-1/2"surface hole will TD above the C-30 sand and then 10-3/4" casing will be set.The intermediate section will be drilled with 9-7/8"x 11"underreamer BHA and Managed Pressure Drilling technology. This hole will be subsequently cased with a 7-5/8"casing string to surface and cemented to 500' above the uppermost hydrocarbon bearing interval. The suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak-off test. The 6-3/4"production section will then be horizontally drilled and completed as a Alpine A sand producer. The well will be completed with a 4-1/2"solid liner with frac sleeves across the productive zone and tied back to surface with a 3-1/2"gas- lifted upper completion string. It is the intention of ConocoPhillips to hydruallically fracture CD5-05 at a later date.' Please find attached the information required by 20 AAC 25.005 (a) and(c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application For Permit to Drill per 20 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035(d)(2) 6. Directional drilling/collision avoidance information as required by 20 AAC 25.050(b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information,please contact Will Earhart at 265-1077 (William.C.Earhart(a,ConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD5-05 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1720 Chip Alvord ATO 1570 Will Earhart Mandy Pogany ATO 1766 Drilling Engineer Lanston Chin Kuukpik Corp • Applic.for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 CD5-05 Application for Permit to Drill Document mining sameitif fez ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005 (c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005 (c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005 (c)(12) CD5-05 APD Page 1 of 15 Printed: 17-Apr-15 • AppliSfor Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005 (c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005 (c)(14) 15. Attachments 10 Attachment 1 Cement Summary 11 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Completion Schematic 15 Attachment 4 Directional Plan 16 CD5-05 APD Page 2 of 15 Printed: 17-Apr-15 • Applicillfor Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as CRU CD5-05. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for Location at Surface 316' FNL,2517' FEL, Sec. 18,T11N,R4E,UM NAD 1927 RKB Elevation 70.3'AMSL Northings: 5,965,894 Eastings: 349,462 Pad Elevation 34.0'AMSL Top of Productive Horizon(Heel) 3904'FNL,756'FEL, Sec. 8,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 11,277' Northings: 5,967,447 Total Vertical Depth, RKB: 7,453' Eastings: 356,528 Total Vertical Depth, SS: 7,383' Total Depth (Toe) 4797'FNL,2749'FEL, Sec. 16,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 18,307' Northings: 5,961,213 Total Vertical Depth, RKB: 7,542' Eastings: 359,714 Total Vertical Depth, SS: 7,472' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. CD5-05 APD Page 3 of 15 Printed: 17-Apr-15 • Applic•for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Size Csg Setting Depth Fracture Pore pressure ASP Drilling (in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 20 110/ 110 10.9 50 51 10.75 2,504/2,350 14.5 1,077 1,537 7.625 11,277/7,453 12.5 3,094 2,502 N/A 18,307/ 7,542 12.5 3,256 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FG x 0.052)-0.1]*D 32if '52 Where: ASP=Anticipated Surface pressure in psi �� • 0 FG=Fracture gradient at the casing seat in lb/gal o 0.052=Conversion from lb./gal to psi/ft �j,3 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(0.1 x D) Where: FPP=Formation Pore Pressure at the next casing point FPP=0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20"conductor ASP= [(FG x 0.052)-0.1]D =[(10.9x0.052)-0.1]x 110=51 psi OR ASP=FPP-(0.1 x D) = 1077-(0.1 x 2350')=842 psi 2. Drilling below 10-3/4"surface casing ASP=[(FG x 0.052)-0.1]D = [(14.5 x 0.052)-0.1]x 2350' = 1537 psi OR ASP=FPP-(0.1 x D) =3094-(0.1 x 7453')=2349 psi 3. Drilling below 7-5/8" intermediate casing ASP=[(FG x 0.052)-0.1]D =[(12.5 x 0.052)-0.1]x 7453=4099 psi OR ASP=FPP-(0.1 x D) =3256-(0.1 x 7542')=2502 psi (B)data on potential gas zones; CD5-05 APD Page 4 of 15 Printed: 17-Apr-15 ApplicSfor Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 The well bore is not expected to penetrate any gas zones. (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) Sirz'� (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 80 30/30 110/ 110 Previously Installed HYD Cement to Surface with 10-3/4 13.5 45.5 L-80 563 X 2,468 36/36 2,504/2,350 1173 sx ASLite Lead 11.2 ppg, BTCM 273 sx Class"G"Tail Slurry 15.8 ppg 9.875 HYD 7-5/8 x11 29.7 L-80 563 X 11,241 36/36 11,277/7,453 260 sx Class G at 15.8 ppg BTCM 4-1/2 6.75 12.6 L-80 IBT-M 7,207 11,100/7,434 18,307/7,542 N/A—uncemented liner with frac sleeves 3-1/2 6.75 9.3 L-80 EUE 11,064 36/36 11,100/7,434 N/A-production tubing 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). CD5-05 APD Page 5 of 15 Printed: 17-Apr-15 • Applicill for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 Casing Size in. 10.75 7.625 4.5 Density PPG 8.8— 10.0 9.6— 11.5 9.1 PV cP 30 -80 10 10 YP Ib./100 ft2 100 - 200 20- 28 10 - 15 Funnel Viscosity s/qt. 300 50-60 40 - 50 Initial Gels Ib./100 ft2 50 10 6 10 Minute Gels Ib./100 ft2 60 15 8 API Fluid Loss cc/30 min. N.C. — 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0— 12.0 10.0 pH 11.0 9.5- 10.0 9.0-9.5 Surface Hole: A mixed-metal oxide fresh water drilling fluid(Drilplex)will be used for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight< 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate#1: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids(by diluting as required)will all be important in maintaining wellbore stability. The mud will be weighted up to 11.5 before pulling out of the hole. Note: Managed Pressure Drilling(MPD)will be utilized for added backpressure to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill-in fluid(FloPro)weighted to 9.1 ppg with calcium carbonate and KCI. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-05 APD Page 6 of 15 Printed: 17-Apr-15 • Applic.for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto CD5-05. 2. Rig up and test riser,dewater cellar as needed. 3. Rig up diverter and test. 4. Drill 13.5"hole to the surface casing point as per the directional plan(LWD Program: GR/RES). 5. Run and cement 10-3/4"surface casing to surface. 6. Install BOPE and MPD equipment. 7. Test BOPE to 250 psi low/3500 psi high. 8. Pick up and run in hole with 9-7/8"x 11"drilling BHA to drill the intermediate pilot hole section. 9. Pressure test casing to 3500 psi. 10. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.0 ppg.Minimum LOT required to drill ahead is 12.5 ppg EMW. 11. Drill 9-7/8"x 11"hole to section TD using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. section cS'ww -_r(7 12. Run 7-5/8"casing and cement to 500' above hydrocarbon bearing zones. 13. Test BOPE to 250 psi low/3,500 psi high. 14. Pick up and run in hole with 6-3/4"drilling BHA.Pressure test casing to 3,500 psi. 15. Drill out shoe track and 20 feet of new formation.Perform LOT to a maximum of 18 ppg.Minimum required leak-off value is 12.0 ppg EMW. 16. Drill 6-3/4"hole to section TD(LWD Program: GR/Azimuthal Res.). 17. Pull out of hole with drilling BHA. 18. RIH with 4.5"liner completion(solid liner with frac sleeves)on 4"drill pipe. 19. Set liner top packer and release from liner. 20. Displace well to seawater. 21. Run 3.5"upper completion. CD5-05 APD Page 7 of 15 Printed: 17-Apr-15 . AppliS for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 22. Space out and land hanger. 23. Install 2-way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 24. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi. Remove 2-way check. 25. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 26. Shear circulation valve in GLM. 27. Circulate tubing to diesel and install freeze protection in the annulus. 28. Set BPV and secure well. RDMO. CD5-05 APD Page 8 of 15 Printed: 17-Apr-15 • Applicefor Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(I4)) Incidental fluids developed from drilling operations on well CD5-05 will be injected into dedicated disposal well CD1-01 A. The CD5-05 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include only the Alpine sand based on pre-drill interpretations. There will be 500' of cement fill placed above the top of the Alpine reservoir. Once CD5-05 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations,per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation(C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes.Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection,the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure =(12.0 ppg) * (0.052) * (Surf. Shoe TVD)+ 1,500 psi =(12.0 ppg) * (0.052) * (2350')+ 1,500 psi =2966 psi Pore Pressure = 1,127 psi Therefore Differential=2966—1127= 1839 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85%collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85%of Burst 85%of (PPOType Collapse Burst 10-3/4" 45.5 L-80 3 HYD563 2470 psi 2100 psi 5210 psi 4429 psi 10-3/4" 45.5 L-80 3 BTC-M 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563 4790 psi 4071 psi 6890 psi 5856 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi CD5-05 APD Page 9 of 15 Printed: 17-Apr-15 • Applic•for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-05 APD Page 10 of 15 Printed: 17-Apr-15 iAppli.for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 Attachment 1 —Cement Summary CD5-05 Cementing Program: CD5-05 wp09 Cementing Schematic 20" We AI Conductor94#Hc-40 to eld110'd 10-3/4"45.5#L-80 HYD563/BTCM 2,504' MD/2,350'TVD @ 42°inc. 9-7/8"x 11" Hole Top of Cement 10,695' MD/7,344'TVD Alpine A 7-5/8"29.7#L-80 HYD563 X BTCM Casing 11,195'MD/7,446'TVD 11,277' MD/7,453'TVD @ 86° 6-3/4" Hole 4-1/2" Liner 12.6 ppf L80 IBT 18,307' MD./7,542'TVD @ 90° CD5-05 APD Page 11 of 15 Printed: 17-Apr-15 • App.for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 10.75" Surface Casing run to 2,504' MD/2,350' TVD Cement from 2504' MD to 2004'(500' of tail)with Class G+Adds. @ 15.8 PPG, and from 1970'to surface with 11.2 ppg Arctic Lite Crete. Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1594' MD), zero excess in 20"conductor. Lead slurry from 2,004'MD to surface with Arctic Lite Crete @ 11.2 ppg Conductor (110'—0') X 1.3645 ft3/ft X 1.0 (0%excess) = 150 ft3 Permafrost to Conductor (1,594'— 110') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,889 ft3 Top of Tail to Permafrost (2,004'— 1,594')X 0.3637 ft3/ft X 1.5 (50%excess) = 224 ft3 Total Volume = 150 + 1,889 + 224 = 2,263 ft3=> 1,173 sx of 11.2 ppg Arctic Lite Crete @ 1.93 ft3 /sk Tail slurry from 2,504'MD to 2,004'MD with 15.8 ppg Class G +additives Shoe to Top of Tail (2,504'—2,004')X 0.3637 ft3/ft X 1.50 (50%excess) = 273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 273 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk 7.625" Intermediate Casing run to 11,277' MD/7,453' TVD Top of slurry is designed to be at 10,695' MD,which is 500' above the Alpine A.Assume 40%excess annular volume. Tail slurry from 11,277'MD to 10,695' MD with 15.8 ppg Class G + additives Shoe to Top of Cement (11,277'— 10,695')X 0.3428 ft3/ft X 1.40 (40%excess) = 280 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) = 21 ft3 Total Volume = 280 + 21 = 301 ft3 => 260 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8%S002 accelerator @ 1.16 ft3/sk CD5-05 APD Page 12 of 15 Printed: 17-Apr-15 • Applic•for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 Attachment 2— Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots,traveling cylinder diagrams Monitor well at base of permafrost,increased mud weight,decreased Gas Hydrates Low mud viscosity,increased circulating times,controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters,Increase mud weight,use weighted sweeps. Lost Circulation Low Reduced pump rates,mud rheology, lost circulation material,use of low density cement slurries 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology, lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems, alarms,standard well control practices, mud scavengers 6-3/4"/4-1/2"Liner Production Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems, alarms,standard well control practices, mud scavengers CD5-05 APD Page 13 of 15 Printed:17-Apr-15 • Applice for Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik and instability in the production interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. CD5-05 APD Page 14 of 15 Printed: 17-Apr-15 • Applicefor Permit to Drill,Well CRU CD5-05 Saved: 17-Apr-15 Attachment 3—Completion Schematic CD5-05 Alpine A Producer Wp09 Proposed Schematic llllii 20"94#H-40 Welded Upper Completion: Length 1)4-1/ 12.6#/ft IBT-M Tubing(2 jts) k Conductor to 114' XO to 3-''/2'EUE tubing 3)Shallow nipple profile 2)3-%"x 1"Camco KBMG GLM (xx°)w/DV 7' 3)3-W x 1"Camco KBMG GLM(xx°)w/DV 7' 4)3'/z"x 1"Camco KBMG GLM(xx°)w/DCK2 7' pinned for 2500 psi casing to tbg shear m 5)SLB BHP Gauge,Encapsulated I-Wire 1.5' 10-3/4"45.5#L-80 w/cannon clamps on every joint 'I" Hydril 563&BTC 6)D nipple 2.812"ID 1.5' Surface Casing 7)WLEG 1.5' 2,504'MD/2,350'TVD©42° cemented to surface Lower Completion: 8)ZXP Liner Top Packer& Flexlock Liner Hanger 37' XO 5"Hydril 521 Box X 4-W IBTM pin 9)D nipple 2.750"ID 1.5' 10)4'A", 12.6#/ft,L-80 IBT-M Liner w/ball actuated frac ports every-750' 11)Perforated pup 3-1/2" 9.3#L-80 EUE 7 5/8"29#L-80 Hyd 563&BTC-M Intermediate Csg to 11,277'MD/7,453'TVD©86° Top Reservoir at+/- Perforated pup Alpine A Sand 7446'TVD 0 0 0 0 0 0 0 0 0 •.0 4-'/Z'12.6#L-80 Liner 6 3/4"Hole TD w/ball drop frac sleeves 18,307'MD/7,542'TVD CD5-05 APD Page 15 of 15 Printed: 17-Apr-15 • • Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Wednesday, April 29, 2015 8:34 AM To: Loepp,Victoria T (DOA) Subject: RE: CRU CD5-04(PTD 215-072);CRU CD5-05(PTD 215-073) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the email. Included are my responses to your questions. Please let me know if you have any further questions or concerns. 1. The diverter schematics both show a building(?)at the outlet identified as a truck loading area? Please clarify The labeled feature tag#5 is a planned truck unloading area- it's a containment area. It is not installed yet so it will not be in our way when we spud 2. Please provide the length of the diverter line 41 teet of 16" diverter line.This is same amount as what was rigged up on CD5-314(PTD 215-039) Since we do not have enough diverter line to reach out to the tundra on this well (due to the shape of the pad),we intend to restrict access to the rear side of the well row in excess to the 75' radius mandated exclusion zone as the tip of the line will be over the gravel. 3. For CD5-04(P + 215-072),there is an anti-collision major risk failure with CD2-33. What mitigation measures will be in place to 4 imize this risk? ne well called o. CD2-33 was a Plugback abandoned i ugust 2001.Two open-hole cement plugs were used to isolate - - Alpine sands-47.7bbl 15.8. "G" cement spotted on bottom @21,454' MD via balanced plug(calculate T. - 20,790'MD). Seco • plug laid on top of first-52.0bbl 15.8ppg"G" cement for final calculated top of ceme if 20,340' D (7,216'TVDss).Top Alpine C in CD2-33 was interpreted as 20,632' MD (7299'TVDss) We therefore judge the risk of a ollision as mi al as the reservoir was competently isolated when abandoned. We will manag- e deviation from ou orporate anti-collision policy internally via the "Tolerable Collision Ris " process. The same will b= ompleted for the anti-collision issue with exploration well "Nuiqsut 1"that was plugged a • .bandoned. 4. Please provide mitigation measures planned for dealing with the water that was encountered in CD5-314(PTD 215-039). At this time we are sourcing equipment to tacilitate a 2-stage surface cement jou along with an external casing- annulus packer to provide additional isolation from the water source on the next surface casing run. We have also discussed moving the surface casing shoe higher if we can confirm the water source is at/below the existing CD5-314 shoe. In the event the shoe depth is altered,we will submit a sundry to approved plan. As of today,we plan to further log CD5-314 to better determine where the water source is coming from. 1 • • DI CD5-05wp09 6.945 Plan Summary UJU _ LCU Alpine A C30 .3 5- Kalubik \ / 17-518"x9-7/8" -5 d - HRZ-. - o,Base Permafrost Alb 97 ,./... m Basal K2` o _ Alb 96 _ K3 0 4100 9000 13500 18000 � 20"x 42" 110-3/4"x 13-1/2' \, ,„----\\ ..,,, Measured Depth ,`�' .„„., ,,,,„.....,_, 0_,..,_ Geodetic Datum: North American Datum 1983 • -120"x 42" Depth Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) • 00. 11.E Z:,,scV _°___10-3/4"x 13-1/2'1 Rig: Doyon 19 o b0° s O cl 0° O° ' i .." ' O 10° °o I7-518"x 9-7/81 I4v2"x 6-314" ` - 0 0° 00° O 1 0 0 0 0 0 0 0 oop o r I I I I I I 1 jl I I I I I I I 1 t I I 36 534 0 2000 4000 6000 8000 10000 12000 14000 0 534 - 720 Horizontal Departure - 330 r-�;. 7®, 30 cos-0zwnonI 720 900 /�w- N®eIFAV� - 900 - 1080 w _41.4 . ill �J� I 1080 - 1260 p - As.,...:-.,.............,...71i-.11r.'� l 1260 - 1440 .660 \ _. 300 !.:..e.10.k.�� r - • n60 1440 - 1620 o "` //aff�/Is�� :4��/i'CO I/ szo - 1800 ���, GD5-02wp07 7..4"......„47c1,51,,,,,/!moi °�i�/fr 9r �a..0 - v.�� ,•S / // 1' Icosal�wo7� 1800 - 2490 CL56-08wp07 - 2490 31 BO . 30 , „ 0 , 3180 - 3860 2 CD5A7wp07 CD5-03wp07 270 �It." &III 3860 - 4550 ` 4550 - 5240 CD5-06wp07 ,'•• . , 5240 - 5920 0' �T�• �W I4: 5920 - 6610 U CD5-04wp09 04 41., 6610 __- 7300 0 I I I I I I I I I I I I I I I I I I I I I I I f 1 - 4 �!� �, ingv,4 7300 - 8680 0 2500 5000 7500 10000 12500 15000 17500 240 ►ip9ee, 120 �gr�.ea 8680 - baso SURVEY PROGRAM t �"1�ili a �\� tvai 10050 - 11430 Surface Location tis s nt ��t 1���i \gyp\\� 11430 - 12800 lepth From Depth To Survey/Plan Tool Ic05as°mml "? °g v,o01h1, 05° 36.30 1350.00 CD5-05wp09(Plan CD5-05) GYD-GC-SS Pad Elevation:34.30 -'210 • 0, r' 150 cos-o<wnosl 2e00 - 14180 1350.00 2350.00 CD5-05wp09(Plan CD5-05) MWD CD54Vay07 t..,i•. �'� 14180 15560 1350.00 2504.86 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC 180cm.o a 15560 16930 2504.86 4004.86 CD5-05wp09(Plan CD5-05) MWD CASING DETAILS 16930 - 18308 2504.86 11277.40 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC TVD MD Name 11277.40 12777.40 CD5-05wp09(Plan CD5-05) MWD 180.60 180.60 20"x 42" Magnetic Model: BGGM2014 T 11277.40 18307.74 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC 2350.60 2504.86 10-3/4"x 13-1/2" Magnetic Model Date: 13-Jun-15 7453.60 11277.40 7-5/8"x 9-7/8" Magnetic Declination: 18.18° 7542.60 18307.74 4-1/2"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 18.18°East SECTION DETAILS 1570.6 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 Base Permafrost 2 534.30 0.00 0.00 534.30 0.00 0.00 0.00 0.00 0.00 KOP:Start 2.1./100'DLS,350°TF,for 502.84' 3 1037.14 10.56 350.00 1034.30 45.50 -8.02 2.10 350.00 -43.94 Start 2.5°/100'DLS,60°TF,for 503.87' 4 1541.01 20.05 23.44 1520.60 170.71 18.41 2.50 60.00 -142.08 Hold for 106.45' -2372.3 5 1647.46 20.05 23.44 1620.60 204.19 32.92 0.00 0.00 -164.83 Start 3.5°/100'DLS,40°TF,for 300' 6 1947.46 28.86 37.48 1893.65 309.10 97.61 3.50 40.00 -227.10 Adjust TF to 61.18°,for 894.47' 7 2841.93 51.14 73.26 2583.21 587.63 574.36 3.50 61.18 -249.20 Hold for 6685.64' 8 9527.57 51.14 73.26 6778.03 2086.85 5559.70 0.00 0.00 767.54 Start 3.5°/100'DLS,70.12°TF,for 1749.83' C30 9 11277.40 86.00 129.00 7453.60 1695.83 7033.46 3.50 70.12 1804.68 CD5-05 1.Heel 091014 JH Hold for 20' 10 11297.40 86.00 129.00 7455.00 1683.27 7048.97 0.00 0.00 1823.05 Start 3.97°/100'DLS,81.5°TF,for 561.23' 11 11858.64 89.50 151.00 7477.30 1256.30 7407.07 3.97 81.50 2368.16 Start 4°/100'DLS,90.07°TF,for 424.98' 12 12283.62 89.50 168.00 7481.04 859.70 7555.35 4.00 90.07 2787.95 Adjust TF to-90.39°,for 403.87' -3757.8 13 12687.49 89.41 151.84 7484.90 481.65 7693.53 4.00 -90.39 3186.62 Hold for 5620.25' K3 14 18307.74 89.41 151.84 7542.60 -4473.31 10345.37 0.00 0.00 8806.55 CD5-05 2.Toe 091014 JH TD:18307.74'MD,7542.6'ND -4011.3 Basal K2 -4422.5 Alb 97 -5542.3 Alb 96 •1 rface Location -72•ri.b k is subject to Change o- - _1 n:a Alpine A O.By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. I Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie Will Earhart • • 10:30,April 17 2015 Easting(5000 usft/in) • . :a, ..'` :S•iii 4et,. C _ ��\ i1 1 • I�1 r Q7P2. CDt CD5-02wp07 CD`2 r �'� ` D 1 ':(....:97P , Ci; ne CDpp- PBp CD 03wp0 CD2-74 . IV: I ' .,CS�-01 P: CD CR.Pwpa7 CD2- �\ jC. 1 \l, �•. D1-47P61 CD 12w .7 1• +`\kP ��\ •. 4:: � r LD1c&�D '(21135D2-7 P P. •2 � �� � �' � LL111-21.B D1 1:0P813 CD2- • \\ •E• �• .r,,. c•• cRW••• \�\ �l i A Ipine 'a. '.� � 110 - C.'-07w.17 CD2- _�� ,,a• ,.. CD1-41P1 CD ;D 13. 1u .17 Nu•sut 1 ' -..•2,,���= ; ,\\��, CD -.T.1 !"..145PB1 CD2-'• ' /. '1•�`,`��� fi® 19 111. �— CD2-33 .•� .,. 1e \\\: .'\`" i1 oZ 1-45 o ® CD4-07 r D_45 co �/ 1-40 N— CD5 Alpine West PadP ,i 14 CD-35A CD2 4' o �►I' D2-33 •1 .2-. 4C - 39 0 r ' C. -47; . .� •\•.1, \ •CD.'•' • ('''.k.'.-47 p04 I `o CD2-•'A p02 • •'D `18 ( 2-51 Z CD2- 7 CD. 58L CD -S7 CD - �q2-.a D4- 7 n.. kVAgi Ci CD5-05wp1' CD4-0' •i. .s;•. �'�' CD2-61wp�6 - CDS�:wp�y CD4- .:';;;j7:,-,V;:' .6 -CD5-11wp07 CD• 304'.,,x`' \ � .Z�� CD4 Nanuq Pa >uc low CD4-322 �_� �_�"• it.,,; q •,' 1 CD5-315PB1 w 10 I P : ::14 s iCD4-321 ���,'�, ,`41 ,vAi. •,-292 Easting(5000 usft/in) • • CD5-05wp09 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 3000 CD5-05 1.Heel 091014,.H 0 0 1500- ; o0 10-3/4" x 13-1/2" o 0 0 7-5/8"x 9-7/8" S Gd rat 0 17) 0 20"x 42" LOX1500- 0 z 0 0 -3000— CD5-05 2.Toe 091014 ,- -4500— 4-1/2"x 6-3/4"- 143 �g.�pO9 ov - -1500 0 1500 3000 4500 6000 7500 9000 10500 12000 West(-)/East(+) (1500 usft/in) • • CD5-05wp09 Section View 0- k Base Permafrost 20"x 42" 0° -' C30 100,0' 1500— . 4000 - L. K3 10-3/4" x 13-1/2" 9°13 Basal K2 §3000— r' ,-/Alb 97 _ 40p4" a aa) 56p0 , Alb 96 76 4500— 00 r o 10p0 a co HRZ Kalubik 3 I— gp00 LCOJu q 6000— in Alpine A U - 9g000' bo- 0 0 0 0 0 0 0co,' --- -- �',�0�' �' 'N M4) Q)CD n �� T T T. co — T T f 7500— 7-5/8"x 9-7/8" CD5-05 1.Heel 091014,.H 4-1/2"x 6-3/4" CD5-05 2.Toe 091014,11-I -1500 0 1500 3000 4500 6000 7500 9000 10500 Vertical Section at 152.00° (1500 usft/in) I i ‘a r ''� tegend „.,€14.,} — PROPOSED WELLS QCPAI OPERATED UNIT 511 Operator 0,0 L38846b` 1 f-1 CPA! LEASE with ADL#, and Filet 0O ca: \\L3308084636-46- 300634 ', 0 ON b \\----- as o ��, COL ILLS '� `� RIVED UNIT ASRC-NP 1 ASRC-NPR2 ASRC-NP ASRC-NPR 0O J. �4 0 . t. fl 1C) %0.w.1 ADL387207 cS� p 932191 47 58 NPR - A _ ______ , cD 0..,s AA092347 _ "IN s 340758 ; SRC-NP' O O O 1 �ti. ' •` Ir380075 034 _. A' - -NPR2 4, �1.1-1,,,440 DL380077 2036 I AA09234 ADL38720 340757 O 932193 j csl ASRC- PR4 11110"� 0 ConocoPhillips �' Alaska, Inc. ..> Proposed CD5 Wells With i ___, N Leases 3-19-2015 AA081817 A0 0.5 1 9325521 ` Miles I 0 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-05 Plan CD5-05 Plan: CD5-05wp09 Report 17 April,2015 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Well Plan:CD5-05 Well Position s-NI-S 0.00 usft +E.1-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 34.30 usft Wellbore Plan CD5-05 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) () (nT) BGGM2014 6/1312015 18.18 80.77 57,528 Design CD5-05wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (") 36.30 0.00 0.00 152.00 4/172015 10:56:14AM Page 2 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3(4)70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Survey Tool Program Date 4/17/2015 From To (usft) (usft) Survey(Wel(bore) Tool Name Description ,4914442444#44.4-4a*, 36.30 1,350.00 CD5-05wp09(Plan CD5-05) GYD-GC-SS Gyrodata gyro single shots 1,350.00 2,350.00 CD5-05wp09(Plan CD5-05) MWD MWD-Standard 1,350.00 2,504.86 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC MVD+IFR AK CAZ SCC 2,504.86 4,004.86 CD5-05wp09(Plan CD5-05) MWD MWD-Standard 2,504.86 11,277.40 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,277.40 12,777.40 CD5-05wp09(Plan CD5-05) MWD MWD-Standard 11,277.40 18,307.74 CD5-05wp09(Plan CDS-05) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace NIS EIW Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 36.30 0.00 0.00 36.30 -34.30 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 29.40 0.00 0.00 0.00 0.00 0.05 1.15 180.60 0.00 0.00 180.60 110.00 0.00 0.00 0.00 0.00 0.19 1.15 • 20"x 42" 200.00 0.00 0.00 200.00 129.40 0.00 0.00 0.00 0.00 0.19 1.15 300.00 0.00 0.00 300.00 229.40 0.00 0.00 0.00 0.00 0.34 1.15 400.00 0.00 0.00 400.00 329.40 0.00 0.00 0.00 0.00 0.48 1.15 500.00 0.00 0.00 500.00 429.40 0.00 0.00 0.00 0.00 0.63 1.15 534.30 0.00 0.00 534.30 463.70 0.00 0.00 0.00 0.00 0.67 1.16 KOP:Start 2.1°1100'DLS,350°TF,for 502.84' 600.00 1.38 350.00 599.99 529.39 2.10 350.00 0.78 -0.14 0.77 1.16 700.00 3.48 350.00 699.90 629.30 2.10 0.00 4.95 -0.87 0.91 1.16 800.00 5.58 350.00 799.58 728.98 2.10 0.00 12.73 -2.24 1.06 1.16 900.00 7.68 350.00 898.91 828.31 2.10 0.00 24.10 -4.25 1.21 1.16 1,000.00 9.78 350.00 997.74 927.14 2.10 0.00 39.05 -6.88 1.37 1.16 1,037.14 10.56 350.00 1,034.30 963.70 2.10 0.00 45.50 -8.02 1.43 1.16 Start 2.51100'DLS,60°TF,for 503.6r 1,100.00 11.43 356.89 1,096.01 1,025.41 2.50 60.00 57.39 -9.36 1.53 1.16 4/172015 10:56:14AM Page 3 COMPASS 5000,1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace NIS EIW Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usA) (usft) (usft) 1,200.00 13.07 5.77 1,193.74 1,123.14 2.50 53.24 78.54 -8.76 1.70 1.16 1,300.00 14.96 12.58 1,290.76 1,220.16 2.50 44.55 102.39 -4.81 1.88 1.17 1,400.00 17.00 17.85 1,386.90 1,316.30 2.50 37.95 128.90 2.48 1.98 1.17 1,500.00 19.14 21.99 1,481.96 1,411.36 2.50 32.88 158.03 13.10 2.08 1.16 • 1,541.01 20.05 23.44 1,520.60 1,450.00 2.50 28.95 170.71 18.41 2.15 1.16 Hold for 106.45' 1,594.24 20.05 23.44 1,570.60 1,500.00 0.00 0.00 187.45 25.67 2.29 1.16 Base Permafrost 1,600.00 20.05 23.44 1,576.02 1,505.42 0.00 0.00 189.26 26.45 2.29 1.16 1,647.46 20.05 23.44 1,620.60 1,550.00 0.00 0.00 204.19 32.92 2.42 1.17 Start 3.5°l100'DLS,40°TF,for 300' 1,700.00 21.49 26.66 1,669.73 1,599.13 3.50 40.00 221.05 40.82 2.58 1.17 1,800.00 24.37 31.77 1,761.83 1,691.23 3.50 36.98 254.96 59.91 2.96 1.18 1,900.00 27.39 35.83 1,851.80 1,781.20 3.50 32.28 291,16 84.25 3.44 1.18 1,947.46 28,86 37.48 1,893.65 1,823,05 3.50 28.62 309.10 97.61 3.70 1.18 Adjust TF to 61.18°,for 894.47' 2,000.00 29.78 40.73 1,939.47 1,868.87 3.50 61.18 329.05 113.84 3.99 1.20 2,100.00 31.75 46.40 2,025.41 1,954.81 3.50 58.35 366.03 149.10 4.56 1.24 2,200.00 33.93 51.44 2,109.44 2,038.84 3.50 53.48 401.58 189.99 5.18 1.28 2,300.00 36.30 55.92 2,191.24 2,120.64 3.50 49.24 435.58 236.35 5.87 1.34 2,400.00 38.82 59.91 2,270.52 2,199.92 3.50 45.58 467.89 288.00 3.22 1.23 2,500.00 41.46 63.47 2,346.96 2,276.36 3.50 42.41 498.41 344.76 3.51 1.27 2,504.86 41.59 63.64 2,350.60 2,280.00 3.50 39.69 499.84 347.64 3.87 1.24 10.314"x 13-112" 2,534.07 42.39 64.60 2,372.31 2,301.71 3.50 39.56 508.37 365.23 3.87 1.24 C30 2,600.00 44.20 66.68 2,420.30 2,349.70 3.50 38.85 527.00 406.41 3.87 1.24 2,700.00 47.02 69.58 2,490.25 2,419.65 3.50 37.34 553.58 472.73 4.48 1.25 4/17/2015 10:56:14AM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Coordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3036.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace NIS EMI Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usk) (tisk) 2.800.00 49.91 72.22 2,556.55 2,485.95 3.50 35.31 578.03 543.46 5.33 1,30 2,841.93 51.14 73.26 2,583.21 2,512.61 3.50 33.55 587 63 574.36 5.74 1.32 Hold for 6685.64' 2,900.00 51.14 73.26 2,619.65 2,549.05 0.00 0.00 600.65 617.67 6.37 1.39 3,000.00 51.14 73.26 2,682.39 2,611.79 0.00 0.00 623.08 692.23 7.49 1.53 3,100.00 51.14 73.26 2,745.13 2,674.53 0.00 0.00 645.50 766.80 8.66 1.69 3,200.00 51.14 73.26 2,807.88 2,737.28 0.00 0.00 667.93 841.37 9.86 1.86 3,300.00 51.14 73.26 2,870.62 2,800.02 0.00 0.00 690.35 915.94 11.09 2.05 3,400.00 51.14 7326 2,933.36 2,862.76 0.00 0.00 712.78 990.51 12.33 2.24 3,500.00 51.14 73.26 2,996.11 2,925.51 0.00 0.00 735.20 1,065.07 13.58 2.44 3,600.00 51.14 73.26 3,058.85 2,988.25 0.00 0.00 757.62 1,139.64 14.84 2.65 3,700.00 51.14 73.26 3,121.60 3,051.00 0.00 0.00 780.05 1,21421 16.11 2.86 3,800.00 51.14 73.26 3,184.34 3,113.74 0.00 0.00 802.47 1,288.78 17.38 3.07 3,900.00 51.14 73.26 3,247.08 3,176.48 0.00 0.00 824.90 1,363.35 18.66 3.29 4,000.00 51.14 73.26 3,309.83 3,239.23 0.00 0.00 847.32 1,437.91 19.94 3.50 4,100.00 51.14 73.26 3,372.57 3,301.97 0.00 0.00 869.75 1,512.48 9.36 2.28 4,200.00 51.14 7326 3,435.31 3,364.71 0.00 0.00 892.17 1,587.05 9.84 2.39 4,300.00 51.14 73.26 3,498.06 3,427.46 0.00 0.00 914.60 1,661.62 10.32 2.50 4,400.00 51.14 73.26 3,560.80 3,490.20 0.00 0.00 937.02 1,736.18 10.81 2.61 4,500.00 51.14 73.26 3,623.55 3,552.95 0.00 0.00 959.44 1,810.75 11.30 2.73 4,600.00 51.14 73.26 3,686.29 3,615.69 0.00 0.00 981.87 1,885.32 11.79 2.84 4,700.00 51.14 73.26 3,749.03 3,678.43 0.00 0.00 1,004.29 1,959.89 12.29 2.95 4,713.99 51.14 73.26 3,757.81 3,687.21 0.00 0.00 1,007.43 1,970.32 12.79 3.07 K8 4,800.00 51.14 73.26 3,811.78 3,741.18 0.00 0.00 1,026.72 2,034.46 12.79 3.07 4,900.00 51.14 73.26 3,874.52 3,803.92 0.00 0.00 1,049.14 2,109.02 13.28 3.19 5,000.00 51.14 73.26 3,937.26 3,866.66 0.00 0.00 1,071.57 2,183.59 13.78 3.30 4/1712015 10:56:14AM Page 5 COMPASS 5000.1 Build 65 0 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc AzI(azimuth) TVD TVDSS DLeg TFace NIS EM Let.Error Vert.Error (usft) (e) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (ustt) 5,100.00 51.14 73.26 4,000.01 3,929.41 0.00 0.00 1,093.99 2,258.16 14.28 3.42 • 5,117.98 51.14 73.26 4,011.29 3,940.69 0.00 0.00 1,098.02 2,271.57 14.79 3.54 Basal K2 5,200.00 51.14 73.26 4,062.75 3,992.15 0.00 0.00 1,116.42 2,332.73 14.79 3.54 5,300.00 51.14 73.26 4,125.50 4,054.90 0.00 0.00 1,138.84 2,407.30 15.29 3.66 5,400.00 51.14 73.26 4,188.24 4,117.64 0.00 0.00 1,161.27 2,481.86 15.79 3.78 5,500.00 51.14 73.26 4,250.98 4,180.38 0.00 0.00 1,183.69 2,556.43 16.30 3.90 5,600.00 51.14 73.26 4,313.73 4,243.13 0.00 0.00 1,206.11 2,631.00 16.80 4.02 5,700.00 51.14 73.26 4,376.47 4,305.87 0.00 0.00 1,228.54 2,705.57 17.31 4.14 5,773.44 51.14 73.26 4,422.55 4,351.95 0.00 0.00 1,245.01 2,760.33 17.81 4.26 Alb 97 5,800.00 51.14 73.26 4,439.21 4,368.61 0.00 0.00 1,250.96 2,780.13 17.81 4.26 5,900.00 51.14 73.26 4,501.96 4,431.36 0.00 0.00 1,273.39 2,854.70 18.32 4.38 • 6,000.00 51.14 73.26 4,564.70 4,494.10 0.00 0.00 1,295.81 2,929.27 18.83 4.50 6,100.00 51.14 73.26 4,627.45 4,556.85 0.00 0.00 1,318.24 3,003.84 19.34 4.62 6,200.00 51.14 73.26 4,690.19 4,619.59 0.00 0.00 1,340.66 3,078.41 19.85 4.75 6,300.00 51.14 73.26 4,752.93 4,682.33 0.00 0.00 1,363.09 3,152.97 20.35 4.87 • 6,400.00 51.14 7326 4,815.68 4,745.08 0.00 0.00 1,385.51 3,227.54 20.86 4.99 6,500.00 51.14 73.26 4,878.42 4,807.82 0.00 0.00 1,407.93 3,302.11 21.37 5.11 6,600.00 51.14 73.26 4,941.16 4,870.56 0.00 0.00 1,430.36 3,376.68 21.88 5.23 6,700.00 51.14 73.26 5,003.91 4,933.31 0.00 0.00 1,452.78 3,451.25 22.39 5.36 6,800.00 51.14 73.26 5,066.65 4,996.05 0.00 0.00 1,475.21 3,525.81 22.90 5.48 6,900.00 51.14 73.26 5,129.40 5,058.80 0.00 0.00 1,497.63 3,600.38 23.42 5.60 7,000.00 51.14 73.26 5,192.14 5,121.54 0.00 0.00 1,520.06 3,674.95 23.93 5.73 7,100.00 51.14 73.26 5,254.88 5,184.28 0.00 . 0.00 1,542.48 3,749.52 24.44 5.85 • 7,200.00 51.14 73.26 5,317.63 5,247.03 0.00 0.00 1,564.91 3,824.08 24.95 5.97 7,300.00 51.14 73.26 5,380.37 5,309.77 0.00 0.00 1,587.33 3,898.65 25.46 6.09 4/172015 10:56:14AM Page 6 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellborn: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVOSS Meg TFace N/S ESN Let.Error Veil.Error (usft) (°) (°) (usft) (use) (1J10tusft) (^) (usft) (usft) (usft) (usft) 7,400.00 51.14 73.26 5,443.11 5,372.51 0.00 0.00 1,609.76 3,973.22 25.97 6.22 7,500.00 51.14 73.26 5,505.86 5,435.26 0.00 0.00 1,632.18 4,047.79 26.49 6.34 • 7,558.11 51.14 73.26 5,542.32 5,471.72 0.00 0.00 1,645.21 4,091.12 27.00 6.47 Alb 88 7,600.00 51.14 73.26 5,568.60 5,498.00 0.00 0.00 1,654.60 4,122.36 27.00 6.47 7,700.00 51.14 73.26 5,631.35 5,560.75 0.00 0.00 1,677.03 4,196.92 27.51 6.59 • 7,800.00 51.14 73.26 5,694.09 5,623.49 0.00 0.00 1,699.45 4,271.49 28.02 6.71 7,900.00 51.14 73.26 5,756.83 5,686.23 0.00 0.00 1,721.88 4,346.06 28.54 6.84 8,000.00 51.14 73.26 5,819.58 5,748.98 0.00 0.00 1,744.30 4,420.63 29.05 6.96 • 8,100.00 51.14 73.26 5,882.32 5,811.72 0.00 0.00 1,766.73 4,495.20 29.56 7.08 8,200.00 51.14 73.26 5,945.06 5,874.46 0.00 0.00 1,789.15 4,569.76 30.08 7.21 8,300.00 51.14 73.26 6,007.81 5,937.21 0.00 0.00 1,811.58 4,644.33 30.59 7.33 8,400.00 51.14 73.26 6,070.55 5,999.95 0.00 0.00 1,834.00 4,718.90 31.10 7.46 8,500.00 51.14 73.26 6,133.30 6,062.70 0.00 0.00 1,856.43 4,793.47 31.62 7.58 8,600.00 51.14 73.26 6,196.04 6,125.44 0.00 0.00 1,878,85 4,868.03 32.13 7.70 8,700.00 51.14 73.26 6,258.78 6,188.18 0.00 0.00 1,901.27 4,942.60 32.65 7.83 8,800.00 51.14 73.26 6,321.53 6,250.93 0.00 0.00 1,923.70 5,017.17 33.16 7.95 8,900.00 51.14 73.26 6,384.27 6,313.67 0.00 0.00 1,946.12 5,091.74 33.67 8.08 9,000.00 51.14 73.26 6,447.01 6,376.41 0.00 0.00 1,968.55 5,166.31 34.19 8.20 9,100.00 51.14 73.26 6,509.76 6,439.16 0.00 0.00 1,990.97 5,240.87 34.70 8.33 • 9,200.00 51.14 73.26 6,572.50 6,501.90 0.00 0.00 2,013.40 5,315.44 35.22 8.45 9,300.00 51.14 73.26 6,635.25 6,564.65 0.00 0.00 2,035.82 5,390.01 35.73 8.57 9,400.00 51.14 73.26 6,697.99 6,627.39 0.00 0.00 2,058.25 5,464.58 36.25 8.70 • 9,500.00 51.14 73.26 6,760.73 6,690.13 0.00 0.00 2,080.67 5,539.15 36.76 8.82 9,527.57 51.14 73.26 6,778.03 6,707.43 0.00 0.00 2,086.85 5,559.70 36.90 8.86 Start 3.5'(100'DLS,70.12°TF,for 1749.83' 9,600.00 52.04 76.29 6,823.04 6,752.44 3.50 70.12 2,101.75 5,614.46 37.21 8.95 4/17/2015 10:56:14AM Page 7 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3(a3 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace N/S EIW Let.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) )usft) (usft) (usft) (usft) 9,700.00 53.41 80.34 6,883.62 6,813.02 3.50 68.24 2,117.83 5,692.35 37.44 9.07 9,800.00 54.91 84.24 6,942.19 6,871.59 3.50 65.79 2,128.68 5,772.66 37.52 9.20 9,895.54 56.45 87.83 6,996.07 6,925.47 3.50 63.51 2,134.12 5,851.36 37.47 9.32 HRZ 9,900.00 56.53 87.99 6,998.53 6,927.93 3.50 61.48 2,134.25 5,855.07 37.47 9.32 10,000.00 58.25 91.61 7,052.43 6,981.83 3.50 61.39 2,134.52 5,939.28 37.31 9.46 10,100.00 60.08 95.08 7,103.69 7,033.09 3.50 59.44 2,129.48 6,024.98 37.04 9.59 10,134.17 60.73 96.24 7,120.57 7,049.97 3.50 57.66 2,126.55 6,054.54 36.68 9.73 Kalublk 10,200.00 62.00 98.43 7,152.12 7,081.52 3.50 57.09 2,119.17 6,111 84 36.68 9.73 10,300.00 63.99 101.66 7,197.54 7,126.94 3.50 56.04 2,103.60 6,199.54 36.25 9.88 10,395.75 65.96 104.65 7,238.05 7,167.45 3.50 54.57 2,083.84 6,284.00 35.74 10.02 LCU 10,400.00 66.05 104.78 7,239.78 7,169.18 3.50 53.30 2,082.85 6,287.76 35.74 10.02 10,500.00 68.17 107.80 7,278.67 7,208.07 3.50 53.25 2,056.99 6,376.16 35.16 10.17 10,600.00 70.35 110.73 7,314.09 7,243.49 3.50 52.08 2,026.12 6,464.42 34.52 10.32 10,700.00 72.57 113.59 7,345.88 7,275.28 3.50 51.04 1,990.35 6,552.21 33.82 10.48 10,800.00 74.84 116.37 7,373.94 7,303.34 3.50 50.13 1,949.81 6,639.19 33.07 10.63 10,869.58 76.43 118.27 7,391.21 7,320.61 3.50 49.35 1,918.88 6,699.07 32.26 10.79 UJU 10,900.00 77.13 119.09 7,398.17 7,327.57 3.50 48.88 1,904.66 6,725.05 32.26 10.79 11,000.00 79.46 121.77 7,418.46 7,347.86 3.50 48.69 1,855.07 6,809.46 31.39 10.95 11,100.00 81.80 124.40 7,434.74 7,364.14 3.50 48.15 1,80122 6,892.12 30.47 11.11 11,195.48 84.06 126.88 7,446.50 7,375.90 3.50 47.72 1,746.00 6,969.11 29.50 11.27 Alpine A 11,200.00 84.16 127.00 7,446.96 7,376.36 3.50 47.41 1,743.30 6,972.70 29.50 11.27 11,277.40 86.00 129.00 7,453.60 7,383.00 3.50 47.40 1,695.83 7,033.46 28.80 11.30 Hold for 20'-7.518"x 9-718" 4/172015 10:56:14AM Page 8 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 • • Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace N/S E/W Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) (usft) 11,297.40 86.00 129.00 7,455.00 7,384.40 0.00 0.00 1,683.27 7,048.97 28.93 11.31 Start 3.971/100'DLS,81.5°TF,for 561.23' 11,300.00 86.02 129.10 7,455.18 7,384.58 3.97 81.50 1,681.64 7,050.98 28.89 11.31 11,400.00 86.61 133.03 7,461.61 7,391.01 3.97 81.49 1,616.09 7,126.20 27.38 11.32 11,500.00 87.22 136.95 7,466.99 7,396.39 3.97 81.24 1,545.51 7,196.80 25.87 11.34 11,600.00 87.85 140.87 7,471.30 7,400.70 3.97 81.03 1,470.22 7,262.45 24.38 11.38 11,700.00 88.48 144.79 7,474.50 7,403.90 3.97 80.86 1,390.59 7,322.82 22.95 11.43 11,800.00 89.12 148.71 7,476.59 7,405.99 3.97 80.74 1,306.99 7,377.63 21.61 11.49 11,858.64 89.50 151.00 7,477.30 7,406.70 3.97 80.65 1,256.30 7,407.07 20.88 11.53 Stall 4°I100'DLS,90.01 TF,for 424.98' 11,900.00 89.50 152.65 7,477.66 7,407.06 4.00 90.07 1,219.84 7,426.60 20.38 11.56 12,000.00 89.50 156.65 7,478.54 7,407.94 4.00 90.06 1,129.48 7,469.39 19.28 11.64 12,100.00 89.49 160.65 7,479.42 7,408.82 4.00 90.03 1,036.37 7,505.78 18.41 11.74 12,200.00 89.50 164.66 7,480.30 7,409.70 4.00 89.99 940.94 7,535.59 17.82 11.84 12,283.62 89.50 168.00 7,481.04 7,410.44 4.00 89.95 859.70 7,555.35 17.55 11.93 Adjust TF to-90.39°,for 403.87' 12,300.00 89.50 167.34 7,481.18 7,410.58 4.00 -90.39 843.70 7,558.85 17.97 11.95 12,400.00 89.47 163.34 7,482.08 7,411.48 4.00 -90.38 746.98 7,584.14 20.66 12.08 12,500.00 89.45 159.34 7,483.03 7,412.43 4.00 -90.35 652.25 7,616.12 23.70 12.21 12,600.00 89.43 155.34 7,484.01 7,413.41 4.00 -90.31 559.99 7,654.63 26.93 12.35 12,687.49 89.41 151.84 7,484.90 7,414.30 4.00 -90.27 481.65 7,693.53 29.83 12.49 Hold for 5620.25' 12,700.00 89.41 151.84 7,485.03 7,414.43 0.00 0.00 470.62 7,699.43 29.99 12.51 12,800.00 89.41 151.84 7,486.05 7,415.45 0.00 0.00 382.45 7,746.62 18.83 11.64 12,900.00 89.41 151.84 7,487.08 7,416.48 0.00 0.00 294.29 7,793.80 19.14 11.69 13,000.00 89.41 151.84 7,488.11 7,417.51 0.00 0.00 206.13 7,840.99 19.47 11.74 13,100.00 89.41 151.84 7,489.13 7,418.53 0.00 0.00 117.97 7,888.17 19.81 11.79 4/172015 10:56:14AM Page 9 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:C05-05 Project: Western North Slope ND Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey • MD Inc Azi(azimuth) ND NDSS DLeg TFace NIS EIW Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 13,200.00 89.41 151.84 7,490.16 7,419.56 0.00 0.00 29.80 7,935.35 20.16 11.84 13,300.00 89.41 151.84 7,491.19 7,420.59 0.00 0.00 -58.36 7,982.54 20.52 11.89 13,400.00 89.41 151.84 7,492.21 7,421.61 0.00 0.00 -146.52 8,029.72 20.89 11.95 13,500.00 89.41 151.84 7,493.24 7,422.64 0.00 0.00 -234.68 8,076.90 21.27 12.01 13,600.00 89.41 151.84 7,494.27 7,423.67 0.00 0.00 -322.85 8,124.09 21.66 12.07 13,700.00 89.41 151.84 7,495.29 7,424.69 0.00 0.00 -411.01 8,171.27 22.05 12.13 13,800.00 89.41 151.84 7,496.32 7,425.72 0.00 0.00 -499.17 8,218.45 22.46 12.20 13,900.00 89.41 151.84 7,497.35 7,426.75 0.00 0.00 -587.33 8,265.64 22.87 12.27 14,000.00 89.41 151.84 7,498.37 7,427.77 0.00 0.00 -675.50 8,312.82 23.28 12.34 14,100.00 89.41 151.84 7,499.40 7,428.80 0.00 0.00 -763.66 8,360.01 23.71 12.41 14,200.00 89.41 151.84 7,500.43 7,429.83 0.00 0.00 -851.82 8,407.19 24.14 12.49 14,300.00 89.41 151.84 7,501.45 7,430.85 0.00 0.00 -939.98 8,454.37 24.58 12.56 • 14,400.00 89.41 151.84 7,502.48 7,431.88 0.00 0.00 -1,028.15 8,501.56 25.02 12.64 14,500.00 89.41 151.84 7,503.51 7,432.91 0.00 0.00 -1,116.31 8,548.74 25.47 12.72 14,600.00 89.41 151.84 7,504.53 7,433.93 0.00 0.00 -1,204.47 8,595.92 25.92 12.81 14,700.00 89.41 151.84 7,505.56 7,434.96 0.00 0.00 -1,292.63 8,643.11 26.38 12.89 14,800.00 89.41 151.84 7,506.59 7,435.99 0.00 0.00 -1,380.80 8,690.29 26.84 12.98 14,900.00 89.41 151.84 7,507.61 7,437.01 0.00 0.00 -1,468.96 8,737.48 27.31 13.07 15,000.00 89.41 151.84 7,508.64 7,438.04 0.00 0.00 -1,557.12 8,784.66 27.78 13.16 15,100.00 89.41 151.84 7,509.67 7,439.07 0.00 0.00 -1,645.29 8,831.84 28.25 13.25 15,200.00 89.41 151.84 7,510.69 7,440.09 0.00 0.00 -1,733.45 8,879.03 28.73 13.35 15,300.00 89.41 151.84 7,511.72 7,441.12 0.00 0.00 -1,821.61 8,926.21 29.21 13.44 15,400.00 89.41 151.84 7,512.75 7,442.15 0.00 0.00 -1,909.77 8,973.39 29.70 13.54 • 15,500.00 89.41 151.84 7,513.77 7,443.17 0.00 0.00 -1,997.94 9,020.58 30.18 13.64 15,600.00 89.41 151.84 7,514.80 7,444.20 0.00 0.00 -2,086.10 9,067.76 30.68 13.74 15,700.00 89.41 151.84 7,515.83 7,445.23 0.00 0.00 -2,174.26 9,114.94 31.17 13.84 15,800.00 89.41 151.84 7,516.85 7,446.25 0.00 0.00 -2,262.42 9,162.13 31.67 13.95 4/172015 10:56:14AM Page 10 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-05 Project: Western North Slope ND Reference: Plan:34.3+36.3(g 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD NDSS DLeg TFace NIS EIW Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (1/100usft) (°) (usft) (usft) (usft) (usft) 15,900.00 8941 151.84 7,517.88 7,44728 0.00 000 -2,350.59 9,209.31 32.17 14.05 16,000.00 89.41 151.84 7,518.91 7,448.31 0.00 0.00 -2,438.75 9,256.50 32.67 14.16 16,100.00 89.41 151.84 7,519.93 7,449.33 0.00 0.00 -2,526.91 9,303.68 33.17 14.27 16,200.00 8941 151.84 7,520.96 7,450.36 0.00 0.00 -2,615.07 9,350.86 33.68 14.38 16,300.00 89.41 151.84 7,521.99 7,451.39 0.00 0.00 -2,703.24 9,398.05 34.19 14.49 16,400.00 89.41 151.84 7,523.01 7,452.41 0.00 0.00 -2,791.40 9,445.23 34.70 14.61 16,500.00 8941 151.84 7,524.04 7,453.44 0.00 0.00 -2,879.56 9,492.41 35.21 14.72 16,600.00 89.41 151.84 7,525.07 7,454.47 0.00 0.00 -2,967.72 9,539.60 35.73 14.83 16,700.00 8941 151.84 7,526.09 7,455.49 0.00 0.00 -3,055.89 9,586.78 36.25 14.95 16,800.00 89.41 151.84 7,527.12 7,456.52 0.00 0.00 -3,144.05 9,633.96 36.76 15.07 16,900.00 89.41 151.84 7,528.15 7,457.55 0.00 0.00 -3,232.21 9,681.15 37.28 15.19 17,000.00 8941 151.84 7,529.17 7,458.57 0.00 0.00 -3,320.37 9,728.33 37.81 15.31 17,100.00 8941 151.84 7,530.20 7,459.60 0.00 0.00 -3,408.54 9,775.52 38.33 15.43 17,200.00 89.41 151.84 7,531.23 7,460.63 0.00 0.00 -3,496,70 9,822.70 38.85 15.55 17,300.00 8941 151.84 7,532.25 7,461.65 0.00 0.00 -3,584.86 9,869.88 39.38 15.68 17,400.00 8941 151.84 7,533.28 7,462.68 0.00 0.00 -3,673.03 9,917.07 39.91 15.80 17,500.00 89.41 151.84 7,534.31 7,463.71 0.00 0.00 -3,761.19 9,964.25 40.44 15.93 17,600.00 8941 151.84 7,535.33 7,464.73 0.00 0.00 -3,849.35 10,011.43 40.97 16.05 17,700.00 89.41 151.84 7,536.36 7,465.76 0.00 0.00 -3,937.51 10,058.62 41.50 16.18 17,800.00 89.41 151.84 7,537.39 7,466.79 0.00 0.00 -4,025.68 10,105.80 42.03 16.31 17,900.00 89.41 151.84 7,538.41 7,467.81 0.00 0.00 -4,113.84 10,152.99 42.57 16.44 18,000.00 89.41 151.84 7,539.44 7,468.84 0.00 0.00 -4,202.00 10,200.17 43.10 16.57 18,100.00 8941 151.84 7,540.47 7,469.87 0.00 0.00 -4,290.16 10,247.35 43.64 16.70 18200.00 89.41 151.84 7,541.49 7,470.89 0.00 0.00 -4,378.33 10,294.54 44.17 16.83 18,300.00 89.41 151.84 7,542.52 7,471.92 0.00 0.00 -4,466.49 10,341.72 44.71 16.97 18,307.74 89.41 151.84 7,542.60 7,472.00 0.00 0.00 -4,473.31 10,345.37 44.75 16.98 TD:18307.74'MD,7542.6'TVD 4/17/2015 10:56:14AM Page 11 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Coordinate Reference: Well Plan:CD5-05 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature Design: CD5-05wp09 Database: OAKEDMP2 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W -Shape (°) (°) (usft) (usft) (usft) CD5.05 1.Heel 091014, 0.00 0.00 7,453.60 1,695.83 7,033.46 -plan hits target center -Circle(radius 100.00) CD5-05 2.Toe 091014 21 0.00 0.00 7,542.60 -4,473.31 10,345.37 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole '. Depth Depth Diameter Diameter • (usft) (usft) Name (in) (in) 180.60 180.60 20"x 42" 20.000 42.000 11,277.40 7,453.60 7-5/8"x 9-7/8" 7.625 9.875 2,504.86 2,350.60 10-3/4"x 13-1/2" 10.750 13.500 18,307.74 7,542.60 4-1/2"x 6-3/4" 4.500 6.750 4/17/2015 10:56:14AM Page 12 COMPASS 5000.1 Build 65 • 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-NMS Local Co-ordinate Reference: 'Well Plan CD5-05 r � Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usf(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-05 North Reference: True Wellbore: Plan CD5-05 Survey Calculation Method: Minimum Curvature , Design: CD5-05wp09 Database: OAKEDMP2 ' Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (1 10,395.75 7,238.05 LCU 4,713.99 3,757.81 K3 1,594.24 1,570.60 Base Permafrost 10,869.58 7,391.21 UJU 7,558.11 5,542.32 Alb 96 10,134.17 7,120.57 Kalubik 5,773.44 4,422.55 Alb 97 2,534.07 2,372.31 C30 9,895.54 6,996.07 HRZ 5,117.98 4,011.29 Basal K2 11,195.48 7,446.50 AlpineA Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 01 ',s. 534.30 534.30 0.00 0.00 KOP:Start 2.1°/100'DLS,350°TF,for 502.84' 1,037.14 1,034.30 45.50 -8.02 Start 2.5°/100'DLS,60°TF,for 503.87' 1,541.01 1,520.60 170.71 18.41 Hold for 106.45' 1,647 46 1,620.60 204.19 32.92 Start 3.5°/100'DLS,40°TF,for 300' 1,947.46 1,893.65 309.10 97.61 Adjust TF to 61.18',for 894.47' 2,841.93 2,583.21 587.63 574.36 Hold for 6685.64' 9,527.57 6,778.03 2,086.85 5,559.70 Start 3.5'/100'DLS,70.12°TF,for 1749.83' 11,277.40 7,453.60 1,695.83 7,033.46 Hold for 20' 11,297.40 7,455.00 1,683.27 7,048.97 Start 3.97°/100'DLS,81.5°TF,for 561.23' 11,858.64 7,477.30 1,256.30 7,407.07 Start 4°/100'DLS,90.07°TF,for 424.98' 12,283.62 7,481.04 859.70 7,555.35 Adjust TF to-90.39°,for 403.87' 12,687.49 7,484.90 481.65 7,693.53 Hold for 5620.25' 18,307.74 7,542.60 -4,473.31 10,345.37 TD:18307.74'MD,7542.6'ND 4/17/2015 10:56 14AM Page 13 COMPASS 5000.1 Build 65 • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-05 Plan CD5-05 CD5-05wp09 Clearance Summary Anticollision Report 17 April,2015 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-05-Plan CD5-05-CD5-05wp09 Well Coordinates: 5,965,640.01 N,1,489,495.40 E(70°18'48.93"N,151°13'23.61"W) Datum Height Plan:34.3+36.3 70.60usft(Doyon 19) Scan Range: 0.00 to 18,307.74 usft.Measured Depth. Scan Radius is 2,027.14 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale FactorApplied Version:5000.1 Build:65 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 2004 100/1000 of reference Scan Type: 25.00 • 0 ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for Plan: CD5-05-CD5-05wpO9 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-05-Plan CD5-05-CD5-05wp09 Scan Range: 0.00 to 18,307.74 usft.Measured Depth. Scan Radius is 2,027.14 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 CD2 Alpine Pad CD2-33-CD2-33-CD2-33 10,025.80 472.97 10,025.80 59.66 20,100.00 1.144 Clearance Factor Pass-Major Risk CD2-33-CD2-33-CD2-33 10,000.00 471.31 10,000.00 63.60 20,150.00 1.156 Centre Distance Pass-Major Risk CD5 Alpine West Pad Plan:CD5-01-Plan:CD5-01-CD5-01wp07 334.30 80.01 334.30 74.16 300.00 13.674 Centre Distance Pass-Major Risk Plan:CD5-01-Plan:CD5-01-CD5-01wp07 434.29 80.88 434.29 73.29 400.00 10.655 Clearance Factor Pass-Major Risk Plan:CD5-02-Plan:CD5-02-CD5-02wp07 384.30 60.00 384.30 53.28 350.00 8.923 Centre Distance Pass-Major Risk Plan:CD5-02-Plan:CD5-02-CD5-02wp07 634.64 62.44 634.64 51.35 600.00 5.629 Clearance Factor Pass-Major Risk Plan:CD5-03-Plan CD5-03-CD5-03wp07 961.20 38.43 961.20 21.55 925.00 2.276 Centre Distance Pass-Major Risk Plan:CD5-03-Plan CD5-03-CD5-03wp07 1,137.94 39.46 1,137.94 19.44 1,100.00 1.971 Clearance Factor Pass-Major Risk Plan:CD5-04-Plan:CD5-04-CD5-04wp09 484.30 20.00 484.30 11.53 450.00 2.361 Centre Distance Pass-Major Risk Plan:CD5-04-Plan:CD5-04-CD5-04wp09 609.27 20.79 609.27 10.41 575.00 2.003 Clearance Factor Pass-Major Risk Plan:CD5-06-Plan:CD5-06-CD5-06wp07 534.30 20.00 534.30 10.66 500.00 2.140 Centre Distance Pass-Major Risk Plan:CD5-06-Plan:CD5-06-CD5-06wp07 684.02 20.89 684.02 8.93 650.00 1.747 Clearance Factor Pass-Major Risk Plan:CD5-07-Plan:CD5-07-CD5-07wp07 534.30 40.00 534.30 30.65 500.00 4.280 Centre Distance Pass-Major Risk Plan:CD5-07-Plan:CD5-07-CD5-07wp07 683.68 40.68 683.68 29.02 650.00 3.488 Clearance Factor Pass-Major Risk Plan:CD5-08-Plan:CD5-08-CD5-08wp07 534.30 60.01 534.30 50.66 50000 6.421 Centre Distance Pass-Major Risk Plan:CD5-08-Plan:CD5-08-CD5-08wp07 3,537.27 118.78 3,537.27 43.16 3,525.00 1.571 Clearance Factor Pass-Major Risk Plan:CD5-09-Plan:CD5-09-CD5-09wp07 384.30 80.01 384.30 73.28 350.00 11.898 Centre Distance Pass-Major Risk Plan:CD5-09-Plan:CD5-09-CD5-09wp07 609.06 81.82 60906 71.19 575.00 7.700 Clearance Factor Pass-Major Risk Plan:CD5-10-Plan:CD5-10-CD5-10wp07 658.44 99.65 658.44 88.53 625.00 8.961 Centre Distance Pass-Major Risk Plan:CD5-10-Plan:C05-10-CD5-10wp07 732.24 100.10 732.24 87.82 700.00 8.157 Clearance Factor Pass-Major Risk Plan:CD5-11-Plan:CD5-11-CD5-11wp07 534.30 120.01 534.30 110.67 500.00 12.842 Centre Distance Pass-Major Risk Plan:CD5-11-Plan:CD5-11-CD5-11wp07 757.64 121.47 757.64 108.22 725.00 9.166 Clearance Factor Pass-Major Risk Plan:CO5-12-Plan:CD5-12-CD5-12wp07 384.30 14001 384.30 133.28 350.00 20.821 Centre Distance Pass-Major Risk Plan:CD5-12-Plan:CD5-12-CD5-12wp07 608.87 141.74 608.87 131.12 575.00 13.342 Clearance Factor Pass-Major Risk Plan:C05-13-Plan:CD5-13-CD5-13wp07 682.50 159.05 682.50 147.59 650.00 13.877 Centre Distance Pass-Major Risk Plan:CD5-13-Plan:CD5-13-CD5-13wp07 755.60 159.43 755.60 146.79 725.00 12.612 Clearance Factor Pass-Major Risk 17 April,2015- 10:24 Page 2 of 5 COMPASS 410 0 ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for Plan: CD5-05-CD5-O5wpO9 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:CD5 Alpine West Pad-Plan:CD5-05-Plan CD5-05-CD5-05wp09 Scan Range: 0.00 to 18,307.74 usft.Measured Depth. Scan Radius is 2,027.14 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:CD5-314-Plan:CD5-314-CD5-314wp14 525.10 179.79 525.10 170.53 525.00 19.403 Centre Distance Pass-Major Risk Plan:CD5-314-Plan:CD5-314-CD5-314wp14 673.72 180.64 673.72 169.26 675.00 15.869 Clearance Factor Pass-Major Risk Plan:CD5-314-Plan:CD5-314PB1-CD5-314PB1wp1 525.10 179.79 525.10 170.53 525.00 19.403 Centre Distance Pass-Major Risk Plan:CD5-314-Plan:CD5-314PB1-CD5-314PB1wp1 673.72 180.64 673.72 169.26 675.00 15.869 Clearance Factor Pass-Major Risk Plan:CD5-315-Plan:CD5-315-CD5-315 wp10 534.30 200.01 534.30 190.67 500.00 21.403 Centre Distance Pass-Major Risk Plan:CD5-315-Plan:CD5-315-CD5-315 wp10 682.83 200.78 682.83 188.92 650.00 16.929 Clearance Factor Pass-Major Risk Plan:CD5-315-Plan:CD5-315PB1-CD5-315PB1 wp 534.30 200.01 534.30 190.67 500.00 21.403 Centre Distance Pass-Major Risk Plan:CD5-315-Plan:CD5-315PB1-CD5-315PB1 wp 682.83 200.78 682.83 188.92 650.00 16.929 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 36.30 1,350.00 CD5-05wp09 GYD-GC-SS 1,350.00 2,350.00 CD5-05wp09 MWD 1,350.00 2,504.86 CD5-05wp09 MWD+IFR-AK-CAZ-SC 2,504.86 4,004.86 CD5-05wp09 MWD 2,504.86 11,277.40 CD5-05wp09 MWD+IFR-AK-CAZ-SC 11,277.40 12,777.40 CD5-05wp09 MWD 11,277.40 18,307.74 CD5-05wp09 - 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. 17 April,2015- 10:24 Page 3 of 5 COMPASS • CD5-05w 09 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 9, 0 ;33 3 8 n,bSm n7o17, ®ono no 0 0 0 CID LAM UW U U U 300 1 I IIII PlI IIIIINII@' I�IIIIIIIIIIIIIHl 1111 Illl'Oil 1 I�IIII II 11 .9 _ I , I ro Ills VIII 1 �' I ii'' a 11 Q Ill I I )' ullulllVppV l ....."11111111111111Il III I'I ll1��' �, 91 , 11 p + 150—Bquwelant Magnetic Distance, :OW 1111 lII IIII I ' I U olllllllllll iII1111! V O ollllllll ! I 101 II N ,• IIIIII�I� ��iIIIP;II� ll� Vulm IIII 11111 llill I� III, ' IpI, _. {l. _. 0 IIIIIIIIIIII III!,II CD2-33 hi �,Illillllll Il lhl,„ .III'ill!IIII, r_IIIIIIIIIIIIIII!i!„, 0 I I I I I I I 1 1 I I I I I I I I I I I I I I I I I 1 1 0 3000 6000 9000 12000 15000 18000 Displayed interval could be less than entire welbMeasured Depth 36.30 To 18307.74 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval:25.00 Depth Range From: 36.30 To 18307.74 Results Limited By: Centre Distance: 2027.14 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1350.00 CD5-05wp09 (Plan CD5-05) GYD-GC-SS 1350.00 2350.00 CD5-05wp09(Plan CD5-05) MWD 1350.00 2504.86 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC 2504.86 4004.86 CD5-05wp09(Plan CD5-05) MWD 2504.86 11277.40 CD5-05wp09(Plan CD5-05) MWD+IFR-AK-CAZ-SC 11277.40 12777.40 CD5-05wp09 (Plan CD5-05) MWD 11277.40 18307.74 CD5-05wp09 (Plan CD5-05) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 180.60 180.60 20"x 42" 20.000 2350.60 2504.86 10-3/4" x 13-1/2" 10.750 7453.60 11277.40 7-5/8"x 9-7/8" 7.625 7542.60 18307.74 4-1/2"x 6-3/4" 4.500 LEGEND —A— CD2-33,CD2-33,CD2-33 V2 $- Plan:CD5-07,Plan:CD5-07,CD5-07wp07 VO —I— Plan:CD5-13,Plan:CD5-13,CD5-13wp07 VO ▪ Plan:CD5-01,Plan:CD5-01,CD5-01wp07 VO —0— Plan:CD5-08,Plan:CD5-08,CD5-08wp07 VO --1— Plan:CD5-314,Plan:CD5-314,CD5-314wp14 VO —X— Plan:CD5-02,Plan:CD5-02,CD5-02wp07 VO —X— Plan:CD5-09,Plan:CD5-09,CD5-094p07 VO $ Plan:CD5-314,Plan:CD5-314P51,CD5-314PB1wpt4 VO —A— Plan:CD5-03,Plan CD5-03,CD5-03wp07 VO —1-- Plan:CD5-10,Plan:CD5-10,CD5-10wp07 VO -0- Plan:CD5-315,Plan:CD5315,CD5-315 wp10 VO Plan:CD5-04,Plan:CD5-04,CD5-04wp09 VO _e_ Plan:CD5-11,Plan:CD5-11,CD5-11wp07 VO --49- Plan:CD5-315,Plan:CD5-315PB1,CD5-315PB1 wp10 VO -e-- Plan:CD5-06,Plan:CD5-06,CD5-06wp07 VO -8- Plan:CD5-12,Plan:CD5-12,CD5-12wp07 VO -8- CD5-05wp09 • • Ladder View CD5-05w 09 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 0 ti. 00 3 a 0. xx M ', . At, 0 0 ® 00 60— � - � �1 .. .. .. «- - I ifi ' ' j // Q f°7 , i --- 11111 , 0 I I I I I 1 I I 1 I I I I I I I I 1 I I I I I 1 1 1 1 1 I 1 I 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire well:Measured Depth 36.30 To 18307.74 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 36.30 To 18307.74 Results Limited By: Centre Distance: 2027.14 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1350.00 CD5-05wp09(Plan CD5-05) GYD-GC-SS 1350.00 2350.00 CD5-05wp09 (Plan CD5-05) MWD 1350.00 2504.86 CD5-05wp09 (Plan CD5-05) MWD+IFR-AK-CAZ-SC 2504.86 4004.86 CD5-05wp09 (Plan CD5-05) MWD 2504.86 11277.40 CD5-05wp09 (Plan CD5-05) MWD+IFR-AK-CAZ-SC 11277.40 12777.40 CD5-05wp09 (Plan CD5-05) MWD 11277.40 18307.74 CD5-05wp09 (Plan CD5-05) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 180.60 180.60 20"x 42" 20.000 2350.60 2504.86 10-3/4" x 13-1/2" 10.750 7453.60 11277.40 7-5/8"x 9-7/8" 7.625 7542.60 18307.74 4-1/2"x 6-3/4" 4.500 LEGEND - CD2-33,CD2-33,CD2-33 V2 -8- Plan:CD5-07,Plan:CD5-07,CD5-07wp07 VO —I— Plan:CD5-13,Plan:CD5-13,CD5-13wp07 VO -A- Plan:CD5-01,Plan:CD5-01,CD5-01wp07 VO -0- Plan:CD5-08,Plan:CD5-0B,CD5-08wp07 VO —1— Plan:CD5-314,Plan:CD5-314,CD5-314wp14 VO —X— Plan:CD5-02,Plan:CD5-02,CD5-02wp07 VO —X— Plan:CD5-09,Plan:CD5-09,CD5-09wp07 VO -9- Plan:CDS-314,Plan:CD5-314PB1,CD5-314PB1wp14 VO -A- Plan:CD5-03,Plan CD5-03,CD5-03wp07 VO —r— Plan:CD5-10,Plan:CD5-10,CD5-10wp07 VO _0,- Plan:CD5-315,Plan:CD5-315,CD5-315 wp10 VO - Plan:CD5-04,Plan:CD5-04,CD5-04wp09 VO -e- Plan:CD5-11,Plan:CD5-11,CD5-11wp07 VO -e- Plan:CD5-315,Plan:C05-315PB1,CD5-315PB1 wp10 VO -e- Plan:CD5-06,Plan:CD5-06,CD5-06wp07 VO _e_ Plan:CD5-12,Plan:CD5-12,CD5-12wp07 VO -B- CD5-05wp09 0 Inc Az] TVD -eN/-S -eE/-W Dleg TFace oed Target ib 534 0.00 0.00 36.30 0.00 0.00 0.00 0.00 00 CD5-05wp09 534.30 0.00 0.00 0.00 0.00 00 534 720 1037.14 10.56 350.00 1034.30 45.50 -8.02 2.10 350.00 -43.94 36.30 To 18307.74 1541.01 20.05 23.44 1520.60 170.71 18.41 2.50 60.00 -142.08 720 900 1647.46 20.05 23.44 1620.60 204.19 32.92 0.00 0.00 -164.83 1947.46 28.86 37.48 1893.65 309.10 97.61 3.50 40.00 -227.10 2841.93 51.14 73.26 2583.21 587.63 574.36 3.50 61.18 -249.20 900 1080 9527.57 51.14 73.26 6778.03 2086.85 5559.70 0.00 0.00 767.54 10:28,April 17 2015 11277.40 86.00 129.00 7453.60 1695.83 7033.46 3.50 70.12 1804.68 CD5-05 1.Heel 091014JH 1080 1260 11297.40 86.00 129.00 7455.00 1683.27 7048.97 0.00 0.00 1823.05 11858.64 89.50 151.00 7477.30 1256.30 7407.07 3.97 81.50 2368.16 1260 1440 SURVEY PROGRAM 12283.62 89.50 168.00 7481.04 859.70 7555.35 4.00 90.07 2787.95 3e6m From Deem To Survey/Plan 31001 12687.49 89.41 151.84 7484.90 481.65 7693.53 4.00 -90.39 3186.62 36.30 1364.00 co5-05wp09(P011c05-05) GVD-GC-ss 18307.74 89.41 151.84 7542.60 -4473.31 10345.37 0.00 0.00 8806.55 CD5-05 2.Toe 091014 JH 1440 1620 1350 00 2350.00 CDS-0544p09(Plan CDS-05) MWD 1350.00 2504.86 C175-05w609(Plan CDS-05) MWO IFR-AN-CAZ-SC 2504.86 400486 C05.050609(Play CDS-05) MWD 1620 1800 2504.86 11277 40 CD5-05w605(Plan CD5-05) MWD.IFRAle-CAZ-SC 11277.40 12777.40 CD5-05w609(Plan CD5-05) MWD 11 277 40 18307.74 CD "IF s-0S4009(Plan CDS-05) 66667. -ANLAZ-SC 1800 ' 2490 CASING DETAILS 2490 3180 TVD MD Name Size 3180 3860 180.60 180.60 20"x 42" 20.000 2350.60 2504.86 10-3/4"x 13-1/2" 10.750 ---. 7453.60 11277.40 7-5/8"x 9-7/8" 7.625 3860 4550 7542.60 18307.74 4-1/2"x 6-3/4" 4.500 4550 5240 5240 - 5920 0/360 5920 ' 6610 �,�IN ate..r PO7 6610 7300 ♦, ` ��• �„ ���'3►�;.'; 7300 - 8680 -30/ ,w �� 0 =�il► - -._u4• , 30 8680 10050 ,. s l �� 9>, 4\ 10050 11430 *7aP'� t'W �7 , std .4'A4 4' %em -!,,J0�� z`- , : N 11430 12800 E„,144PiaF �i1��►� • ! •C�, _ ` Vj' ►• 9°ls��� *► t �:� j _ 12800 14180 114'% , � ''${� � k =�,150----',- „,„,--------_-:_;,,,,5/lA 14180 15560 .444, N. .7":,,t1-1.11174°.'' �1 i�F N., • ` 15560 16930 60/300 ► I�...�i: e./�. �."�Ma p . ����� l ��;//,� I� jam'. :;,moo- �� `. `p•``��, 60 16930 18308 1 1 w ~ a.l.2ii0.:vim.i „17•1,,4,/ ���//OSI Gii4i,'• ' $�� \ 1 e + jimitit• 2OGR•r / „�, . • •/% ..ii f iictia•ti•s 0��_s $ •ii:,774{531. 6•kr* ,� ��. ;5,0. . -1 ig(44t4t+`w\i1'3,:�gvilii 1 IA + '_1 �li4 .i i• '5sa �2 i •"' t mfg,1A cit �C;. ; .=�=,i • .. en¢y�.'w -' // .iilfiilSci�is i. � r' ._. . . ...N, + i 1i l+ tfet, j4i Ale+di{'<414•i =• •tS4 r w�� 'wirill►rpt' '. ttL `*:.:4N s1ix, ,!I ",l �1 \ul������itittill-44 �_ �111r ./y�1w►lli . mi�> _. 314 90/ i > rl/r .r i1i 7i+i •V•'`P \// �� tryI I 90 Hr. 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'41,•, . \ .4 dhl as 1 E I +� tip 3131 I \ y 1i,� a\\\\�a�i 14 4, ps/ •ire • 31 4 A r .r i{ ly • ,, 4� I�� ,y/�/ • .� %iiS.'�: 54.*y= 4�1{A�sib�',i �' !il,'4"l�l t'`� 4\�‘ � � '•1',/ I /���.!/ .. �. +►r'°; "'+ :4' '� 4, �'�i}f!j 1►g a'a'�•�. �a� i�4 ��•i��► � ► 120 -120/240 ... ..' ° k �* is t, 1,fif fi Nk, %.4/1 /•iI���1,144;0,, ♦ � {��"!=1 t�� r•y�yer+R.,•.rek. y+of 9/, �1�,��f/ \�\`\i\\ ►� • �4 ��� ri...di..;i.'.;' z • y• *ly '501 �L, l '':! d 4. 4. -150/210 3r.�rt,' 'ti ,\`_\\ " s ,V®'Po. 0 ,11� FCD -180 180 -tr tr .00544.,0740 $ 0507.50700 r P 0.,67PO i 5.,3.50740 Han CO5115,CD5 215.10 40 "e" Pr 41004740 4Marc 544.50040 -a 7, 005-0..,0740 $ 7 041.0740 + a "" an CDS Mope,.p054,5PMwp10VI Pla.p65-02.PI��0Os-09"50740 $ 00546.Plan 405 05-0..50740 94 p1-.04544.PI-0054500544.00740 $ Pl.CO512.p.OM 12,C052..07V0 $ Plan 005314.P.005314P81.005110001551405 -13- 45505.00. Inc Azi TVD +N/-S .E/-W Dleg TFace sect Target 3b 034 0.00 0.00 36.30 0.00 0.00 0.00 0.00 .00 CD5-05wp09 5 0.00 0.00 534.30 0.00 45.50 0.00 0.00 0.00 -8.02 2.10 350.00 .00 13.94 534 720 1037.14 10.56 350.00 1034.30 36.30 To 8307.74 1541.01 20.05 23.44 1520.60 170.71 18.41 2.50 60.00 -142.08 720 900 1647.46 20.05 23.44 1620.60 204.19 32.92 0.00 0.00 -164.83 1947.46 28.86 37.48 1893.65 309.1097.61 3.50 40.00 -227.10 2841.93 51.14 73.26 2583.21 587.63 574.36 3.50 61.18 -249.20 900 1080 9527.57 51.14 73.26 6778.03 2086.85 5559.70 0.00 0.00 767.54 10:28,April 17 2015 11277.40 86.00 129.00 7453.60 1695.83 7033.46 3.50 70.12 1804.68 CD5-05 1.Heel 091014 JH 1080 1260 11297.40 86.00 129.00 7455.00 1683.27 7048.97 0.00 0.00 1823.05 11858.64 89.50 151.00 7477.30 1256.30 7407.07 3.97 81.50 2368.16 1260 1440 SURVEY PROGRAM 12283.62 89.50 168.00 7481.04 859.70 7555.35 4.00 90.07 2787.95 39vm From Depth To Survey/Plan Tool 12687.49 89.41 151.84 7484.90 481.65 7693.53 4.00 -90.39 3186.62 36.30 1350.00 C13505,05(Plan C05-o5) GYD-GC-ss 18307.74 89.41 151.84 7542.60 -4473.31 __ _10345.37 0.00 0.00 8806.55 CD5-052.TDe 091014 JH 1440 1620 135000 235000 C05-05w609(P0n C05-05) MWD 135000 250486 C05-05w608(Plan CD5-05) MWD.IFRAK-CAZ-SC 2504.86 400406 CD5-0509(Plan CDS-05) MWD 1620CDS-05,09 1800 2504.86 11277.40CD5-0511p09(Plan C135-05) MWD.IFR-AK-CAZ-SC 1127).40 12121.40 CD5-05,06(Plan CD5-05) MWD 11277.40 18307.74 C0565,09(Plan CD545) MWD.IPR-AK-CAZ-SC 1800 2490 CASING DETAILS 2490 3180 TVD MD Name Size 3180 3860 180.60 180.60 20"x 42•• 20.000 2350.60 2504.86 103/4"x 13-1/2" 10.750 3860 4550 7453.60 11277.40 7-5/8"x 9-7/8•' 7.625 7542.60 18307.74 4-1/2"x 6-3/4" 4.500 4550 5240 - 5240 5920 0/360 5920 6610 6610 7300 CD5-4s:/ 1ii�:�0=r2i190F42:2� 7300 8680 30/330/ �- �%��r': ` 30 8680 10050 .00 ,: ` 10050 11430 ,,�I/��r�/�jam- -�;. ,,�QEN� Z` �; 11430 12800 �=,..40,......e.,....,„„-- iij=`� = =°- ,,�.,` .. 12800 14180 i 1 ���ir-cT>..,4.-,.ill��\ arae, ` `r! ♦ /i I,, �'%moi/i�,.:�,r- ►�ti,.L *� ,` F�.��♦ 14180 15560 /,. .:1- ,x, r/�/�, •♦ 2"...: e v 15560 16930 -60/300 ��/�� I ISI':4 �.--j$0�� - ,„.44.0.0.-72,,,,,,.0,• ,` e04., `it, Pj 16930 18308 � i '-:...4IV1...--0...„..........4...,0,,,,,,,,morz�.♦ ���- �� 4 !! li i ���� =7�� ¢ man �1 "r Z. 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C05-01.00100 t w 005.,«04,00 t PlanCOO 12 Plan:CDS.13.CDS 13w001Y3 -e- 4- 12. 00501.50500 � Pian 050..00900 P" WS.00504.53100 1 PM D5-0.04100 + R ,"005 310401.COSI/SPE11 2.010 VO 4( "C0502.PI-cos 02 C0502",0100 s P.".co 4*.PI."00 CD5-06.00100 44- PI."00500.PI.,CDS 02 00509.07 00 "� 520 005,2.PI."005 a.COS.,2940100 $ Plan 005014.P24 005.014751.003014761.313 00 -$ COS 05-00 0 10:29,April 17 2015 Easting(5000 usft/in) _ IIIlrlrurIIrLiI , , , , I , , I , 1 , , , , „ J , lIJEEI , , , , I , , , , I , ! , , I , 1 , , J , IJ , iu11111LI1 , 1 J , 111 , 1 11 , , , I - -�M :F �. CDS 02wp07 _ CD,03wp07 CD Ag.,e.wpa7 - CD-12ww7 •5-04wp09 CD2 Alpine Pad C• -07wp07 D:1', .17 113 = S=i _ y CD2-33 - Z —o 0. o uo o- CD5 Alpine West Pad a �� -o /'1 O .! o O 7 Z - CD5- 1wp07 _ CD5-05wpl9 CD5-08wp07 CD5-11 wp07 CD4 Nanuq Pad — CD5-315PB1 wp10 — CD5-314PB1wp14 CD5-315 wp10 CD5-314wp14 Easting(5000 usft/in) AC Flipbook Errors Report Pool Report • • 10:38,April 17 2015 WELLBORE TARGET DETAILS(MAP CO-ORDINATES) CD5-051/Vp09 Marne ND Shape0 5-051.Hee1 JH 1453.60 Circle(Radius:100.00) 00 CD5-05 2.Toe 091014 JH 75542.60 Circle(Radius:100.00) Quarter Mile View CDS-05 1.1be 91014 J H OdA 7543 60 Circle(Radius:1320.00) CDS-05 2.T 091014 JH Circle 7542.60 Cirt1e(Radius:1320.00) 10 .2.75 Q2Y v• v. ur v- N=. • 0,,IMIliroo#0713:741,1\0441 :4.r.4 Nui su CP 11"41, .:=,4 _�����►%/...,411e.<04 / �*o I I m AO- 6000 - Irv, 7 ,f 'q 1 \ Go2�v iiii 1 -,,0.,. •.3000 _ iii(iIAS ` -A A• ii.sr, CD2 a G I'it: liikj°2-34 Got • �0 • oea ,t.. + , c GQ2y6 /0.2.,6s cot a O z 2y6�1 GOZ�16 c°2,60.er OOO �� cQ CD4. ,kQ - O 05, 6-1 0•Ntp9 GQ-..5 G,V' p co .. Nae0 Pa GocQaA \ -6000 o `��� 6° _ 11„ `-r .....' 6°P 9000 cD• ° cot -3000 0 3000 6000 9000 12000 15000 18000 2100) West(-1/East(+) (3000 usft/inl • • WELLBORE TARGET DETAILS(MAP CO ORDINATES ','°` # ' CD5-05wp09 Name TVD Shape CD5051.Heel 091014tH 7453.60 Circle(R tlus'.100.00) CD5-052.Toe 091014 JH 754260 Circle(Radius'.100.00) Quarter Mile View C5-051 Heel091014754260 Circle(Radius 132000) C55-05 2.Hee 091014 J14 Circle Circle rA 7453 60 Circle(Radium.1320 00) 6000 x3000 O a 0 w Ilk O a MA 0 LkL i o Z -j-3 000 oOSA yb 04 C‘I Ce- -6000 I 8 -9000 - -3000 0 3000 6000 9000 12000 15000 18000 21000 West(-)/East(+l (3000 usft/in) • • 3-D View CD5-05wp09 emu .................................... .................................................................................................................... Alb 97 ............................................... Alb 96 EEEE OEM SE CD5-O5wpO•/ • • CD5-05wp09 3-D View 30 Alb 96 cos-oswpo• - • • CD5-05wp09 Surface Location t CPAI Coordinate Converter 1 0 I LI Orlis&immei From: To: Datum: INAD83 .l Region: lalaska Datum: (NAD27 . Region: alaska • ,' Latitude/Longitude 'Decimal Degrees r" Latitude/Longitude !Decimal Degrees 7.1 - UTM Zone: 1 1- South € C UTM Zone: [True 1- South State Plane Zone: iiim: Units: LI-j-i 1 C State Plane Zone: True j Units: Jus•ft rrr{De.,cripbon IN ,L,:, ,,, (;' Legal Description(NAD27 only) Starting Coordinates: i Legal Description X: 11489495.40 Township: ir-011 N Range: 1004 ii--;i: Y: 15965640.01 Meridian: IU .. Section:118 FNL • 1315.84813 FEL 12516.6559 Transform I Quit I Help l 1 CD5-05wp09 Intermediate Casing I e Itl. CPAI Coordinate Converter ; Lai (t! ,sof From: To: Datum: INAD83 . Region: Ialaska . Datum: 1NAD 27 .I Region: ledaska .1 C Latitude/Longitude 'Decimal Degrees J } ' Latitude/Longitude (Decimal Degrees . r UTM Zone r------ _ 7 South C UTM Zone: True 7 South a State Plane Zone: 4 1 Units: us ft . C State Plane Zone: True Units: us ft i 1 C ;_ruga"De;.:criptIon 1NAD27 only) 6' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11496561.00 Township; 011 F1/4,— ..--2 Range: 1004 [ii] Y: 15967194.00 Meridian: u Section:l8 NL� 139038562 FEL 1756.43175 { Transform I Quit ( Help 0 Ill 1 CD5-05wp09 TD Q. CPAI Coordinate Converter From: To: Datum: INAD83 . Region: lalaska v I Datum: NAD27 v Region: lalaska 7_1 C Latitude/Longitude 'Decimal Degrees A . Latitude/Longitude 'Decimal Degrees 1 : r- UTM Zone: 1--- E South ts UTM Zone: iTrue E South (iState Plane Zone: 14---.,,. Units: rlls-ft v r State Plane Zone: [-FILTE, Units: us-ft ( Legal De. . .,,,%,,,,.:.,..., ;,',„.j (;: Legal Description(NAD27 only) 1 ,...--J Starting Coordinates: Legal Description X: 11499748.00 Township. 1011 iii Range: fair 11A Y: 15960960.00 Meridian: ru ---":1 Section:116 FrIll '4797.1829 FEC1. 12748.8226 1--- Transform i Quit I Help , . • • Tollerable Collision Risk Worksheet As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 1 ##/##15 CZ DB C.A. UPDATED PER K150003ACS ALL CONDUCTOR ARE LOCATED IN PROTRACTED SEC. 18, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FNL FWL GND PAD CD5-x01 27.6 34.1 CD5-x02 28.1 34.1 CD5-x03 28.4 34.1 CD5-x04 26.6 34.2 CD5-x05 28.1 34.3 CD5-x06 27.7 34.3 CD5-x07 27.9 34.3 CD5-x08 28.1 34.3 CD5-x09 27.3 34.2 CD5-x10 28.1 34.1 CD5-x11 27.9 34.1 CD5-x12 28.0 34.1 CD5-x13 26.1 34.2 CD5-x14 5,965,591.356 1,489,322.327 70' 18' 48.414" 151' 13' 28.633" 365' 2240' 27.6 34.2 CD5-x15 26.8 34.2 NOTES: _. KUUKPIK 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ,,E,�,„,. Alrpine Survey Office ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE-CD50-### 1 of 3 1 SOSl11.Z-S0-4102 1011M331 31 31404641906VA VV 100 10010.A z a g a i •�m - '// t 0 c. 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Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 29, 2015 2:56 PM To: Dai, Weifeng; Samuell, John G Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CD5 well, CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so, at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent:Wednesday, April 29, 2015 1:32 PM To: Bettis, Patricia K (DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log (include Neutron/Density) in intermediate section BHA in CD5-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng 1 • Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuell, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: FW: [EXTERNAL]Mudlog CD5-Pad Fyi Sent with Good (www.good.com) From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Wednesday,April 29, 2015 2:14:45 PM To: Samuell,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL)Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) 02/S —0.F3 From: Bettis, Patricia K (DOA) Sent: Wednesday, April 29, 2015 2:56 PM To: 'Dai, Weifeng';John.G.Samuell@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CD5 well, CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so, at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai,Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent:Wednesday, April 29, 2015 1:32 PM To: Bettis, Patricia K (DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log (include Neutron/Density) in intermediate section BHA in CDS-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuel!, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: FW: [EXTERNAL]Mudlog CD5-Pad Fyi Sent with Good (www.good.com) 1 �' • • From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent:Wednesday, April 29, 2015 2:14:45 PM To:Samuell,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL]Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) 7 J 1 o /S —v-73 From: Bettis, Patricia K (DOA) Sent: Wednesday, April 29, 2015 11:15 AM To: John.G.Samuell@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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(cbalaska.gov. 1 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 28,2015 11:21 AM To: 'william.c.earhart@cop.com' Subject: CRU CD5-04(PTD 215-072);CRU CD5-05(PTD 215-073) Will, 1. The diverter schematics both show a building(?)at the outlet identified as a truck loading area? Please clarify 2. Please provide the length of the diverter line 3. For CD5-04(PTD 215-072),there is an anti-collision major risk failure with CD2-33. What mitigation measures will be in place to minimize this risk? 4. Please provide mitigation measures planned for dealing with the water that was encountered in CD5-314(PTD 215-039). 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.Loeppalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • Bettis, Patricia K (DOA) 7 a13--073 From: Earhart, Will C [William.C.Earhart@conocophillips.com] Sent: Tuesday, April 21, 2015 1:26 PM To: Bettis, Patricia K(DOA) Subject: RE: CD5-04: Permit to Drill Application Patricia, We plan to run gamma and resistivity LWD in the 9-7/8" intermediate sections on CD5-05. This will be the same for CD5-04 intermediate, as well. Sorry for missing that information. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart(7conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, April 21, 2015 1:12 PM To: Earhart, Will C Subject: [EXTERNAL]CD5-04: Permit to Drill Application Good afternoon Will, For the 9 7/8" inch intermediate hole, what logs does ConocoPhillips plan to run? The proposed drilling program discusses the logging progam for the surface hole and the production hole, but there is no LWD program mentioned for the intermediate 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 • • 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: PTD: 215 — 0?-3 ✓Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: ( I /lL ��J POOL: c:1 / F IAJ Ar AiinL. O i Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: / Well Logging Requirements ✓ Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 110 • -I ❑ , , , , , , CA O a) a a) v) fA ° a uY . � E co TD a . . , 2 ; . . . , , n , 3• . . . .. ui r--'o ' . c o, , , , vi N P. E. v W -c ii o(Ooco 0 — coa . of -o 3 o a Z, fes; y, . CC. a 3. co '=O' = a a- ° 3', aLO ro. -° (1) o , w 3. a) �, co a. c. LO 9 -5o) 3 � ° a W E. 2, °. U a o; 1-43 > a >, c) to v Q v °. . o Z . F � of � a O2, No. � ' vmo J a' �. °' w O L 3. U . a). , 'O, V N. C 3�. p U) J COao , �. co OE' o C ,a � o0, � N 4 0 @ w CO ma) Dc. c . ° c o Zn o Cu �. O.E a) 11J $, L, •3. V, C. 0. �• a) a) O. V. 'CO N, cn y d. O. , •!'' z z. 0. J, M. M. 'Q, aY a). 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