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• S Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a1 Ll...- 074 Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: •olor Items: ❑ Maps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: icalatf./A5— /s/ 64p r Project Proofing BY: C Maria Date: 00171.11S-4 /s/ 04 P Scanning Preparation Lk x 30 = f 0 + 3 = TOTAL PAGES 1 43 r (Count does not include cover sheet) 04 BY: -4120 Date: i a gyps- /s/ Production Scanning Stage 1 Page Count from Scanned File: I 1-1-'4- (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES 'nNAO BY: da:b Date: r4 ,� /S' /s/ f/Vt,f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 11410 NO TOTAL PAGES: 5V Digital version appended by: Meredith Michel Date: I c2/30(/s— /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 1 I/— Scanning is complete at this point unless rescanning is required. 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I— N N 0 F ,- I _ N Z 016 5 N CO CD C COW cz W Y t as V/ m Y C 0 Q Y t 1 1 Q a Z O co C C a) U c c E co co as 0j U Z m m as CO CO CO CO m CO CO m m co m co m co m a) m co co m CO CO CO CO CO CO m V CO m CO CO CO V • N- 1 0 0 0 0 0 0 0 0 0 0 0 CD0 0 0 0 0 a)mI c N m m COm COm COm m COm CD COm m S a 7a CD To 6 S c ❑ 0 0 0 0 0 ❑ 0 0 0 0 J 0 0 0 0 0 J E 0 ❑ 0 ti > I M M M M M M co M co M co co co co co co co M 0 LU 0 F- N N N N N N N N N N N N CO CO CO CO O O O IC !r I M lf) LO l0 M l0 U) U) (O CO CO CO CO CO W0 N N N N N N N N N N NN N N N N N N ISW N a N W E E 1 z co ea 0 m o N O m U) z O co d "„ '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I V CL O O d 0 ❑ 00 ❑ 0 0 0 ❑ 0 ❑ 0 p 0 0 0 0 0 p ' Z Q et 2 W LU LU W W LU W W LU W W J LU LU W W W J • S c I 0 0 ( 1' CC) N t0 F. r N o-) Z >- >- >- E N csi CO o c> . I I., o m m N 2 C m < O c:iU) O 0 Z a t 0 Er. 0 a m Q O N 2 00 0 0 � I J_ �/ J a) 1 Ci IX Q 2 �0 : O. `_ :° m CL o J 5 W = N m o. a m m ce OLL W O 61 N Z J@ 0) a V °v o w 0 o rn ` 0• J a C 7 a> 7 E 0a. '6 0 U CLinc I 2 T O 0 ON a r E V V (V O C w o) d E o c c a Q - v F— alN E N V O Z I- 0 w O co c COal RI > N 0 E a) re0, o E .T. 7 ra CO f0 U co C a a c ` ° ICC 11 I Y ° c m 0 •! !:0n _ 111)E U ? O E 0 6 2 0 Z d 7 V X41 0 0 CO �J N N fN0 11,N o } o co G J 0 'I m E N d N O - N = N d N N ` 1 LU m1 re on H m V 0 °; c p r-- co c Z c O w o p ao 0 0 R o p « U .� U J � N d 0 la V E a 7 0 a 0@ y E a p d o E 2 N 0 O 5 G o O Q 01 Co 2(+ovg WELL LOG TRANSMITTAL S ,. PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED $1 5/2oiS K BENDER To: AOGCC R E( Makana Bender 333 West 7th Avenue AUG 0 4 201:i Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Coil Flag 16-Jul-15 2E-01 CD 50-029-20467-01 2) Signed : /' 2', ' ' 64,04 Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM WAchivesW asterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillips_Tran Smit.docx STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdow n Performed: Suspend fl Perforate Other Stimulate n Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r. Re-enter Susp Well rOther: r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pw Exploratory r 214-076-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23516-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25658,25665,25666,392364 KRU 2E-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil.lao7t9 11.Present Well Condition Summary: - 2 I ED Total Depth measured 18670 feet Plugs(measured) none JUL 9 201t) true vertical 6267 feet Junk(measured) none AOGCC Effective Depth measured 18670 feet Packer(measured) 11493 true vertical 6267 feet (true vertical) 5963 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107 107 SURFACE 4912 10.75 4939 3255 INTERMEDIATE 12534 7.625 12560 6161 LINER 6281 4.5 18650 6266 Perforation depth: Measured depth: perf intervals from 17314-17334, 17807-17827, 9 frac ports-see attached schematic True Vertical Depth: perf intervals 6247-6248,6258-6259, 9 frac ports see attached schematic Tubing(size,grade,MD,and TVD) 3.5, L-80, 12393 MD,6143 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PRODUCTION PACKER @ 11493 MD and 5963 TVD NIPPLE-CAMCO DS NIPPLE @ 498 MD and 497 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 348 3107 7 -- 190 Subsequent to operation 314 2140 7 -- 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory f Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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 none Contact John Peirce (,265-6471 Email John.W.Peircetu7conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature 64 W Phone:265-6471 Date 7/2c7 /i S V77 x/30`5 RBDMS AUG - 2 2015 Form 10-404 Revised 5/2015 Submit Original Only 4E-01 WELL WORK SUMMARY • DATE SUMMARY 7/16/2015 B&C CTU #1: PERFORM DEPTH DETERMINATION LOG WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. TAG BRIDGE IN TUBING AT 12244' CTMD AND ABLE TO JET THROUGH BRIDGE AT 2 BPM FROM 12244'-12344'WITH CHOKE CLOSED. COME OFFLINE WITH PUMP AND DRY DRIFT TO 18000' CTMD, DID NOT TAG. LOG UP OVER PERF INTERVAL, PAINTING TIE IN FLAGS ABOVE ZONES. WILL RETURN THE MORNING TO START PERFORATING. 7/17/2015 B&C CTU #1: PERFORATE LOWEST MISSED HORIZONTAL INTERVAL FROM 17,807'- 17,827' RKB WITH SLB 2-IN HSD GUNS (2006-PJ-NOVA, 6 SPF, 60 DEG), CORRELATED TO FRAC PORTS DEPTH ON MEMORY LOG USING DEPTH CORRECTED FLAGS. WILL RETURN TO PERF UPPER ZONE IN THE MORNING. 7/18/2015 B&C CTU #1: PERFORATE HORIZONTAL INTERVAL FROM 17,314'- 17,334' RKB WITH SLB 2-IN HSD GUNS (2006-PJ-NOVA, 6 SPF, 60 DEG), CORRELATED TO FRAC PORTS DEPTH ON MEMORY LOG USING DEPTH CORRECTED FLAGS. JOB COMPLETE. • f 1 KUP PROD 2E-01 Air r ConocoPhillips .iw Well Attributes Max Angle&MD TD P . Aleska,inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) conamRalgpr 500292351600 KUPARUK RIVER UNIT PROD 91.99 13,006.40 18,670.0 ••• . .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Rig Release Date 2E-01,729/20152.09:21 PM SSSV:NIPPLE 16 2/15/2015 Last WO: 27.50 9/23/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 24.1-ii.„.. .,,, Last Tag:CTMD 12,320.0 5/29/2015 Rev Reason:CORRECT PERF TYPES hipshkf 7/29/2015 v� ': Casing esspnogs OD D(n) ID(in) Top(ftKB) Set Depth'ftKB) Set Depthp (TVD( Wt/Len(I...Grade Top Thread IIll: CONDUCTOR 16 15.250 27.6 106.6 106 6 62.50 H-40 Welded XO Enlarging 65.2 ` Casing p (in) ID(in) TopftKB Set Depth ftKB Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 26.9 4,939.0 3,254.8 45.50 L-80 HYD 563 .A.A1 CONDUCTOR;27.6-106.6-,"Mr Casing Description OD(in) ID(in) Top(MB) Set Depth IRKS) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.0 12,560.3 6,160.8 29.70 L-80 Hyd 563 NIPPLE;497.5 ^ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,368.6 18,650.0 6,266.3 12.60 L-80 Hyd563 GAS LIFT;3,309.7 C Liner Details 9 k. ■ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;26.9-0,939.012,368.6 6,140.5 83.97 PACKER HRD ZXP LINE TOP PACKER 4.820 GAS LIFT;6,440.3 12,388.2 6,142.6 84.07 NIPPLE RS PACKOFF SEAL NIPPLE 4.270 12,390.6 6,142.8 84.08 HANGER FLEX LOCK LINER HANGER 4.800 GAS LIFT;8,617.8 MS 12,574.6 6,162.4 83.75 SWELL TAM SWELL PACKERr(14) 3.958 IMS GAS LIFT;10,199.9 PACKER 12,723.7 6,172.4 89.57 FRAC PORT BAKER FRAC SLEEVE 2.700 GAS LIFT;11,416.0 12,823.7 6,171.9 90.95 SWELL TAM SWELL PACKER(13) 3.958 PACKER i !, 13,009.9 6,166.9 91.97 SWELL TAM SWELL PACKER(12) 3.958 SLIDING SLV;11,443.2 - PACKER GAUGE;11,467.9 _ 13,324.7 6,159.5 90.59 FRAC PORT BAKER FRAC SLEEVE(9)2.01"seat for 2.063"ball 2.700 PACKER;11,492.7 13,675.4 6,167.7 87.27 SWELL TAM SWELL PACKER(11) 3.958 NIPPLE;11,520.9 _ PACKER E 13,776.9 6,172.9 87.10 SWELL TAM SWELL PACKERr(10) 3.958 LOCATOR;12,361.4 b,. PACKER 1 14,008.4 6,181.2 87.98 FRAC PORT BAKER FRAC SLEEVE(8)1.948"seat for 2"ball 2.700 MULE SHOE;12,391 9 i' (' 14,275.8 6,188.7 88.49 SWELL TAM SWELL LPACKER(9) 3.958 PACKER I ; 14,506.7 6,194.4 88.31 FRAC PORT BAKER FRAC SLEEVE(7)seat for 1.938"ball 2700 14,731.7 6,199.7 88.52 SWELL TAM SWELL PACKER(8) 3.958 INTERMEDIATE;25.9-12.560.3 PACKER 14,964.4 6,204.5 88.89 FRAC PORT BAKER FRAC SLEEVE(6)seat for 1.875"ball 2.700 PERFP;12,723.6.12,725.9- C"' 15,231.4 6,215.2 87.26 SWELL TAM SWELL PACKER(7) 3.958 PACKER ®- 15,375.4 6,220.5 88.57 SWELL TAM SWELL PACKER(6) 3.958 PACKER tir 15,649.7 6,218.0 90.10 FRAC PORT BAKER FRAC SLEEVE(5)seat for 1.813"ball 2.700 15,959.4 6217.8 89.97 SWELL 'TAM SWELL PACKER(5) 3.958 PERFP;13,324.7-13,327.0--09 6""- PACKER Hydraulic Fracture:12,574.6 16,276.7 6,227.0 87.32 FRAC PORT BAKER FRAC SLEEVE(4)seat for 1.688"ball 2.700 ® 16,544.0 6,235.8 88.94 SWELL TAM SWELL PACKER(4) 3.958 ® PACKER 16,860.1 6,237.5 8924 FRAC PORT BAKER FRAC SLEEVE(3)seat for 1.625"ball 2.700 PERFP;14,008.4-14,010.7 TT.1 N- 17,167.8' 6,244.9 89.14 SWELL Tam Swell Packer(3) 3.958 PACKER ®' 17,439.1 6250.4 88.36 FRAC PORT Baker Frac sleeve(2)1.51"seat for 1.563"ball 2.700 17,746.9 6257.4 89.04 SWELL Tam Swell Packer(2) 3.958 PERFP;14,506.7-14,509.0 t"' PACKER ® 18,021.6 6261.6 89.62 FRAC PORT Baker Frac sleeve(1)1.448"Seat for 1.50"ball 2.700 18,330.9 62612 90.57 SWELL Tam Swell Packer(1) 3.958 PERFP;14,964.4-14,966.7- t! PACKER 18,523.9 6,261.9 88.43 SLEEVE(DEH) PACKERS PLUS DEH,BTC 3.750 Mall 18,597.6 6,264.3 87.84 SLEEVE(TCS) PACKERS PLUS TCS,4-1/2"BTC 1.000 Mill Hydraulic Fracture;14,275.8 Tubing Strings PERFP;15,649.6-15,651.9al E"' Tubing Descnphon String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) TGrade Top C �'' Connection TUBING 4 t/2x31/2 31/2 2.992 24.1 12,393.0 6,143.1 9.30 L-80 EUE 8rd lilill.. @ 65.2 Completion Details _ -e - PERFP;16,276.7-16,279.0- l Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) ® 24.1 24.1 0.00 HANGER CIW TUBING HANGER 3.910 65.2 65.2 0.08 XO Enlarging XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 2.937 EUE 8RD-Mod pin PERFP,16860.1-16,862.4 497.5 497.4 2.34 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 ® 11,443.2 5,950.6 74.32 SLIDING SLV BAKER CMU SLIDING SLEEVE w/DS nipple w/2.813" 2.810 profile APERF;17,314.0-17.334.0 11,467.9 5,957.1 75.03 GAUGE SCHLUMBERGER GAUGE CARRIER 2.992 PERFP,17,439.1-17,441.3 I! 11,492.7 5,963.4 75.73 PACKER BAKER PREMIER PRODUCTION PACKER 2930 Bin 11,520.9 5,970.1 76.53 NIPPLE CAMCO"D"NIPPLE 2.750 APERF;17,0070-17,027.0 -- 12,361.4 6,139.8 83.77 LOCATOR SHEAR PINNED FLUTED NO-GO SUB 3.000 12,391.9 6,143.0 84.08 MULE SHOE MULE SHOE WLEG 2.980 -1 C Hydraulic Fracture;17,746.9 Perforations&Slots lliiiiiiii Shot Dens Top(TVD) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ft)(B) Zone Date t) Type Corn 12,723.7 12,725.9 6,172.4 6,172.4 9/20/2014 PERFP FRAC PORT 13,324.7 13,327.0 6,159.5 6,159.4 9/20/2014 PERFP FRAC PORT 11 14,008.4' 14,010.7 6,1812 6,181.3 9/20/2014 PERFP FRAC PORT LINER;12,368.6.18,050.0 . • 4 KUP PROD 2E-01 ConocoPhillips y Alaska.Inc. Conocerhil8ps 2E-01,7/29/20152:09:23 PM Vertical schematic(actual) .....HANGER 24:1............... g,... , ........ — Perforations&Slots IIS Shot Dens Top(ND) Btm(ND) (shotstf XO Enlarging,65.2 ��—� Top(ftKB) Btm(ftKB) (ftK8) (ftKB) Zone Date t) Type Com ..A.A./CONDUCTOR;27.6-106.6 : il '■� 14,506.7 14,509.0 6,194.4 6,194.4 9/20/2014 PERFP FRAC PORT 14,964.4 14,966.7 6,204.5 6,204.6 9/20/2014 PERFP FRAC PORT NIPPLE;497.5 '- '� 15,649.7 15,651.9 6,218.0 6,218.0 9/20/2014 PERFP FRAC PORT GAS LIFT:3,309.7 16,276.7 16,279.0 6,227.0 6,227.1 9/20/2014 PERFP FRAC PORT i II 7 16,860.1 16,862.4 6,237.5 6,237.6 9/20/2014 PERFP FRAC PORT SURFACE;26.9-0,939.0 ., 17,314.0 17,334.0 6,247.2 6,247.6 7/18/2015 6.0 APERF 2"HSD GUNS PJ NOVA GAS LIFT;6,440.3 CHARGES,60 DEGREES GAS LIFT;6,617.8 17,439.1 17,441.3 6,250.4 6,250.4 9/20/2014 PERFP FRAC PORT . 17,807.0 17,827.0 6,258.4 6,258.7 7/19/2015 6.0 APERF 2"HSD GUNS 60 mom DEGREE,PJ NOVA GAS LIFT;10,199.9 ZSME CHARGES inGnsupr,11.41s.o Stimulations&Treatments V ---!,,!!!.11,1!!:,:,:':,v,;,,, . Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) it SLIDING SLV;11.443.2 (11KB) (ftKB) (ftKB) (ftKB) Type Date Com 12,574.6 14,275.8 6,162.4 6,188.7 Hydraulic 12/12/201 Pumped Stages 8-11,Total of 428,936#16/20 GAUGE;11,467.9 _ Fracture 4 proppant ?' 14,275.8 16,544.0 6,188.7 6,235.8 Hydraulic 12/9/2014 Pumped Stages 4-7,Total of PACKER;11,492.7 r Fracture 391,642#of proppant NIPPLE;11,520.9 17,746.9 18,330.9 6,257.4 6,261.2 Hydraulic 10/27/201 Pumped 112,000#16/20 proppant Fracture 4 LOCATOR;12,361.4 Mandrel Inserts St F -4 ati MULE SHOE;12.391.9 'I'1 I'-. :'.lj on Top(ND) Valve Latch Port Size TRO Run 'I / N. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,309.7 2,604.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,326.0 1/13/2015 10 1l; 2 6,440.3 3,878.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,355.0 1/12/2015 INTERMEDIATE;25.9-12,560.3 3 8,617.9 4,805.2 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 1/12/2015 DCK-2 4 10,199.9 5,459.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/14/2015 I( 5 11,416.0 5,943.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/13/2015 PERFP;12,723.6-12,725.9 Notes:General&Safety y ;; _ _ End Date Annotation ■ NOTE PERFP;13,324.7-13,3270 Hydraulic Fracture;12,574.6 ■ PERFP;14,008.4-14,010.7 PERFP;14,506.7-14,509.0 1 iI 1 . PERFP;14,964.4-14,966.7 1a4 ■. Hydraulic Fracture;14,275.8 i_y _4 PERFP;15649615,651.9 —! PERFP;16,276.7-16,279.0 8 € 1I PERFP;16,660.1-16,862.4 'y - APERF;17,314.0-17,334.0 PERFP;17,439.1-17,441 3— i APERF;17,807.0-17,827.0 II Hydraulic Fracture;17,746.9 4 ✓ LINER;12,3686-18,650.0 STATE OF ALASKA RECEIVED ALAI,OIL AND GAS CONSERVATION COMIVION JAN 2 6 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r' Rug Perforations r Perforater Other (�� (�(1C X01�,�.+ Alter Casing "" Pull Tubing r Stimulate- Frac Fr, Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development gi Exploratory r _ 214-076-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23516-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25658,25665,25666,392364 KRU 2E-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 18670 feet Plugs(measured) none true vertical 6267 feet Junk(measured) none Effective Depth measured 18670 feet Packer(measured) 11493, 12369 true vertical 6267 feet (true vertical) 5963, 6141 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107 107 SURFACE 4912 10.75 4939 3255 INTERMEDIATE 12534 7.625 12560 6161 LINER 6281 4.5 18650 6266' Perforation depth: Measured depth: frac ports from 12724-18524 True Vertical Depth: frac ports from 6172-6250 Tubing(size,grade,MD,and TVD) 3.5, L-80, 12393 MD,6143 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PRODUCTION PACKER @ 11493 MD and 5963 TVD PACKER-HRD ZXP LINER TOP PACKER @ 12369 MD and 6141 TVD NIPPLE-CAMCO DS NIPPLE @ 498 MD and 497 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12575-18524 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in - Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic 16.Well Status after work: Oil Gas r WDSPL Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP "' 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: 314-568 Contact A.,-m Klem @ 263-4529 Email Adam.Klem@conocophillips.com Printed Name 1:am Klem Title Sr. Completions Engineer Signature s Phone:263-4529 Date ,/7/3//5 1/rt 1/7-F1/5T Form 10-404 Revised 10/2012 5 mit Original Only RBDMSA JAN 2 6 2015 • • • C a) E E Lr. o e;, 0 V 0.6 N O N O a) O O 0 0 N a) zzC zC0 zzC0 zC0 zzC0 zC0 C zC 0 C C 0 0 0 0 0 (ZS 2S5 I7S F IL [l5g ZZ F+ © C c0 c0 c0 0) (0 �' ( i' N- ,- ,- .- 6 � LO LO O O .� C co I� LU 0) O 0 O .1- CN CO LU E E O .0 N O r O O N O O '� '� .�-- O O O O O O O O O Ce (T3 coo vv X L C T th O O {� N o0 o a a a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 LY C 0 0 0 0 0 0 0 0 0 0 0 ✓ U 7 p Q) 0 0 0 0 0 0 0 0 0 0 0 N ' LCI IIL L 3 a E � 0 0 � M o 0 0 0 U v• X C a T C o v O V c� .\ a) r.-,/ U i! 0 _ .>i r . a) a *k E EU) o- o- N Z v0 L ) U C Q N n (6 16 N O U Z co i Lo co A 1- ti N 0; N • Nco y� fn O V N O Q r) d N `p- 1; 0 0 r o < z o 0 0 Q °' a` Csl N- 0`. — 0 C u) a N CD Li TCO co n C 3 co c) Q d 'Cl- (6 0 C (1) O 0 M t` O O C a `m Y 0 a) O O O GD O CO Q) a) o E 'X a 0 C) () 0 O' 2 0 ta co O 0 Z N O -- w ) L o o r E N N 0_ O 0) (C) N- < d d' CC o o 0 o CO CO N N 0 TD a N O c N O CO Z p) wCO ° `o a 0 o, m a) E m ,c O L C a) CO (f) C N O m L C..) O O U LO m L N E U = o CI)ff o a) a) N f� E E 0 0 is o E X c,.)- o 4-' 00 (� 2 .0 cu 2 . E o 0 CI N CI o s a a �a _ -9 O E U U W t/) Q (1) U 0 W CO N O U -a / n L� Q Li ..0 C Q con o a) N0 .O C m L . o C 4 ++ @ C c 0 N ti a)•� 0 U) 2 n a) 7/3 Na) Ca o m o 'CO m o C LL j C2. c.) a u) c. 0 u) csi o 'ii a) m 6 C _ E _ a n s) E . ki a = 0 0U) o f E ._ E 5 a� _2 n - 'a-.) V U Z `O Z o J E L.L. co o _o _a .0 a 111 J 'i U 7 C c E E E E E E 03 ci) (0 C F- : O 1JJ C 0 0 0 0 7 L O Q a) (0 Q) s- 0 C) 0 0 cam) 0 0 Q o > 5 U U) U) n U) (� a) v V 0 (6 o E 7 (6 O ou a) Z L- F- z u. E 0 0 CD u) v Z N L cCD o o _ 1-O = ~ m �o M 0 co U 0Ln in ti • • O 00 U O 0 0 0 0 • 0 CCC 0000 z° z° z_ z° 6 6 A A o (N w m m O O CO CO a- 00 0 0 0 0 CO O O O O 0 0 0 0 q. 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O` co na Cu c 7 a). y E U E p N.x 7 y O N 0N O U_ E d E cp a E 7 a, UL, C2 L Y CO 0 0 u) t)] j 0 O d 00c m E m > o O 7 L a, CO o11, 0E C N Cu N I1 C E LL m N Lf)(N 0 C aj 0O N H O M z C f KUP PROD i 2E-01 ConocoPhillips m Well Attributes Max Angle&MD TD A(1$1 a,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm((tKB) ca.,..4hitfip, 500292351600 KUPARUK RIVER UNIT PROD 91.99 13,006.40 18,670.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2E-01,12/22/2014 2,1022 PM SSSV:NIPPLE Last WO: 27.50 9/23/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .......................... HANGER 24.1- _ Last Tag. Rev Reason:FRACTURING hipshkf 12/22/2014 Casing Strings "' ""'" '" • -'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 27.6 106.6 106.6 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread XO Enlarging;652 SURFACE 103/4 9.950 26.9 4,939.0 3,254.8 45.50 L-80 HYD 563 .h.J CONDUCTOR;27.6-106.6 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread lip,. INTERMEDIATE 75/8 6.875 26.0 12,560.3 6,160.8 29.70 L-80 Hyd563 NIPPLE;497.5I Casing Description OD(in) ID(in) Top MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,368.6 18,650.0 6,266.3 12.60 L-80 Hyd563 GAS LIFT;3,309.7 Liner Details .1Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;26.9.4939.0 12,368.6 6,140.5 83.97 PACKER HRD ZXP LINE TOP PACKER 4.820 GAS LIFT;6440.3 III r, 12,388.2 6,142.6 84.07 NIPPLE RS PACKOFF SEAL NIPPLE ' 4.270 12,390.6 6,142.8 84.08 HANGER FLEX LOCK LINER HANGER 4.800 GAS LIFT;8,617.8 i' 12,574.6 6,162.4 83.75 SWELL TAM SWELL PACKERr(14) 3.958 PACKER GAS LIFT;10,199.9 12,723.7 6,172.4 89.57 FRAC PORT BAKER FRAC SLEEVE 2.125 12,823.7 6,171.9 90.95 SWELL TAM SWELL PACKER(13) 3.958 GAS LIFT;11,416.0 Mt PACKER 13,009.9 6,166.9 91.97 SWELL TAM SWELL PACKER(12) 3.958 SLIDING SLV;11,443.2 PACKER 'It 13,324.7 6,159.5 90.59 FRAC PORT BAKER FRAC SLEEVE(9)2.01"seat for 2.063"ball 2.063 GAUGE;11,467.9 PACKER;11,492.7 , 13,675.4 6,167.7 87.27 SWELL TAM SWELL PACKER(11) 1958' ill PACKER NIPPLE;11,520.9 13,776.9 6,172.9 87.10 SWELL TAM SWELL PACKERr(10) 3.958 LOCATOR;12,361.4 b',PACKER 14,008.4 6,181.2 87.98 FRAC PORT BAKER FRAC SLEEVE(8)1.948"seat for 2"ball 2.000 MULE SHOE;12,3919 11P'- ('. 14,275.8 6,188.7 88.49 SWELL TAM SWELL LPACKER(9) 3.958 I! PACKER 14,506.7 6,194.4 88.31 FRAC PORT BAKER FRAC SLEEVE(7)seat for 1.938"ball 1.938 i t 14,731.7 6,199.7 88.52 SWELL TAM SWELL PACKER(8) 1958 INTERMEDIATE;25.9-12,560.3 PACKER 14,964.4 6,204.5 88.89 FRAC PORT BAKER FRAC SLEEVE(6)seat for 1.875"ball 1.875 15,231.4 6,215.2 87.26 SWELL TAM SWELL PACKER(7) 1958 PERFP;12,7236-12,7259 ---fl r- PACKER 15,375.4 6220.5 88.57 SWELL TAM SWELL PACKER(6) 3.958 PACKER 15,649.7 6,218.0 90.10 FRAC PORT BAKER FRAC SLEEVE(5)seat for 1.813"ball 1.813 15,959.4 6,217.8 89.97 SWELL TAM SWELL PACKER(5) 3.958 PACKER PERFP;13,324,7-13,327.0 Hydraulic Fracture;12,574.6 16,276.7 6,227.0 87.32 FRAC PORT 'BAKER FRAC SLEEVE(4)seat for 1.688"ball 1.688 iliaii.- 16,544.0 6,235.8 88.94 SWELL TAM SWELL PACKER(4) 3.958 PACKER IITrll- 16,860.1 6,237.5 89.24 FRAC PORT BAKER FRAC SLEEVE(3)seat for 1.625"ball 1.625 17,167.8 6,244.9 89.14 SWELL Tam Swell Packer(3) 3.958 PERFP;14,008.4-14,010.7 " PACKER 17,439.1 6,250.4 88.36 FRAC PORT Baker Frac sleeve(2)1.51"seat for 1.563"ball 1.563 ® 17,746.9 6,257.4 89.04 SWELL Tarn Swell Packer(2) 3.958 PACKER PERFP;14,50E7 14,509.0 18,021.6 6,261.6 89.62 FRAC PORT Baker Frac sleeve(1)1.448"Seat for 1.50"ball 1.500 ®- 18,330.9 6261.2 90.57 SWELL Tarn Swell Packer(1) 3.958 PACKER PERFP;14,964.4-14,966.7 -+mi rt.- 18,523.9 6,261.9 88.43 SLEEVE(DEH) PACKERS PLUS DEH,BTC 3.750 aIligili- 18,597.6 6,264.3 87.84 SLEEVE(TCS) PACKERS PLUS TCS,4-1/2"BTC 1.000 Tubing Strings Hydraulic Fracture;14,275.8 Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection PERFP;15,649.6-15651.9--7 C•" TUBING 4)/2x 3)/2 3 1/2 2.992 24.) 12,393.0 6,143.1 9.30 L-80 EUE 8rd @65.2 Completion Details iiiiiir Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) PERFP;16,276.7-16,279.0 --2 I: 24.1 24.1 0.00 HANGER CIW TUBING HANGER 3.910 65.2 65.2 0.08 XO Enlarging XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 2.937 ® EUE 8RD-Mod pin 497.5 497.4 2.34 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 PERFP;16,860.1-16,862.4 "I.J 1. 11,4432 5,950.6 74.32 SLIDING SLV BAKER CMU SLIDING SLEEVE w/DS nipple w/2.813" 2.810 - ® profile I 11,467.9 5,957.1 75.03 GAUGE SCHLUMBERGER GAUGE CARRIER 2.992 PERFP;17,439.1-17,441.3 11,492.7 5,963.4 75.73 PACKER BAKER PREMIER PRODUCTION PACKER 2.930 11,520.9 5,970.1 76.53 NIPPLE CAMCO"D"NIPPLE 2.750 12,361.4 6,139.8 83.77 LOCATOR SHEAR PINNED FLUTED NO-GO SUB 3.000 12,391.9 Perforations&Slots 6,143.0 84.08 MULE SHOE MULE SHOE WLEG 2.980 Hydraulic Fracture;17,746.9 Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ft)(B) (ftKB) (ftKB) Zone Date t) Type Com 12,723.7 12,725.9 6,172.4 6,172.4 9/20/2014 PERFP FRAC PORT 13,324.7 13,327.0 6,159.5 6,159.4 9/20/2014 PERFP FRAC PORT 14,008.4 14,010.7 6,181.2 6,181.3 9/20/2014 PERFP FRAC PORT LINER;12,368.6-18,650.0 KUP PROD • 2E-01 ConotoPhillips Alaska,Inc. C n n •hilhps 2E-01,12/22/2014 2:1024 PM Vertical schematic(actual a, ■ Perforations&Slots Shot Dens }, Top(ND) Btm(ND) (shots// 50 Enlarging 65.2 �- , Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com '.�,� .ndc� 14,506.7 14,509.0 6,194.4- 6,194.4 -9/20/2014 PERFP FRAC PORT CONDUCTOR;27.6-106.6- '` 14,964.4 14,966.7 6,204.5 6,204.6 9/20/2014 PERFP FRAC PORT NIPPLE;497.5 15,649.7 15,651.9 6,218.0 6,218.0 9/20/2014 PERFP FRAC PORT GAS LIFT;3,309.7 - ^� 4 16276.7 16,279.0 6,227.0 6,227.1 9/20/2014 PERFP FRAC PORT /"„ 16,860.1 16,862.4 6,237.5 6,237.6 9/20/2014 PERFP FRAC PORT 17,439.1 17,441.3 6,250.4 6,250.4 9/20/2014 PERFP FRAC PORT SURFACE;26.9-4,939.0 GAS LIFT;6,440.3 1 Stimulations&Treatments Min Top ' Max Btm Depth Depth Top(TVD) Btm(ND) GAS LIFT;8,617.8 IC (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 17,746.9 18,330.9 6,257.4 6,261.2 Hydraulic 10/27/201 Pumped 112,000 6 16/20 proppant GAS LIFT;10,199.9 Mk Fracture 4 14,275.8 16,544.0 6,188.7 6,235.8 Hydraulic - 12/9/2014 Pumped Stages 4-7,Total of Fracture 391,642#of proppant GAS LIFT;11,416.0 int ' 12,574.6 14,275.8 6,162.4 6,188.7 Hydraulic 12/12/201 Pumped Stages 8-11,Total of 428,9366 16/20 Fracture 4 I proppant SLIDING SLV;11,443.2 • ... Mandrel Inserts iii St — GAUGE;11,467.9 ati °^ Top(ND) Valve Latch Port Size TRO Run PACKER;11,492.7 _ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 3,309.7 2,604.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 NIPPLE;11,5209 += 2 6,440.3 3,878.9 CAMCO 'KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 - LOCATOR;12,361.4 � 3 8,617.9 4,805.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/6/2014 DCK-2 F 4 4 10,199.9 5,459.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 MULE SHOE;12,391.9 1P. 5 11,416.0 5,943.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 I Notes:General&Safety E End Date Annotation NOTE INTERMEDIATE;25.9-12,560.3 t--` )j PERFP;12723.6.12,725.9 ■ PERFP;13,324.7-13,327.0 I Hydraulic Fracture;12,574.6 ■ PERFP;14,008.4-14,0107 PERFP;14,506.7-14,509.0 PERFP;14,964.4-14,966.7 /19 ■ Hydraulic Fracture;14,275.8 PERFP;15,649.6.15,651.9 I PERFP;16,2767-16,279.0 — PERFP;16,860.146,8624III PERFP;17,439.1-17,441,3 a Hydraulic Fracture;17,746.9 _ I LINER;12,3686-18,6500 1 2401 FRAC SUMMARY DATE SUMMARY 10/6/2014 DEPLOYED CATCHER w/PULLING TOOL. PULLED SOV, SET DV @ 8618' RKB. ATTEMPTED MIT TBG 4000 PSI, FAILED. IN PROGRESS. 10/7/2014 PULLED CATCHER/PULLING TOOL @ 11427' SLM. MIT TBG 4000 PSI, PASSED. MIT IA 3500 PSI, PASSED. PULLED BALL& ROD @ 11503' SLM. ATTEMPTED PULL RHC. IN PROGRESS. 10/8/2014 PULLED RHC @ 11521' RKB. READY FOR FRAC. 10/27/2014 Completed first stage of multi stage frac, pumped first ball followed by 106 bbls flush, well locked up rapidly, approx 12k sand left in well bore, attempted to push a couple bbls freeze protect in tree, RDMO. 10/28/2014 PUMPED 16 BBL HOT DSL @ MIN. RATE WHILE GAUGED TBG TO 2.67"TO 7052' SLM. TOOLS QUIT FALLING, RECOVERED CARBOLITE ON TOOLS. PUMPED ADDN'L 4 BBL DSL, RAN 2.5" BAILER TO 6520' SLM. RECOVERED THICK MILKY FLUID. READY FOR CTU. 10/29/2014 GOT LOCATION RIGGED UP FOR COIL, COIL BACKED IN AND RIGGED UP, PUMPED 11 BBLS INTO WELL 5.5 BBLS @ .5 BPM=2855, 5.5 BBLS @ 1 BPM=3876 PSI, RESTART IN THE MORNING. 10/30/2014 RIH TO 12650' CTMD, DID NOT SEE ANY WT BOBBLES, DID A TUBING SWAP TO DIESEL, WHILE DOWN HOLE WE PUMPED DOWN THE TUBING 1 BPM= 2200 PSI 2 BPM=2880 PSI 3 BPM= 3650 PSI PULLED OUT OF HOLE. ONCE AT SURFACE WE TRIED TO INJECT ONE LAST TIME, @ .5 BPM=3975 PSI. WELL IS FULL OF DIESEL TURN BACK OVER TO FRAC 11/5/2014 Verified injectivity pumping 2.3 bpm, pressured out @ 3500 psi at 4.7 bbls away. Watch pressure falloff to original starting pressure and repeated pumping 3.3 bpm for 3.4 bpm reaching 3500 psi. Watched pressure falloff back to starting pressure. 11/5/2014 ESTABLISHED AN INJECTIVITY RATE OF 6.56 GPM @ 1500 PSI. 11/7/2014 Attempted to increase injectivity thru repeatedly pressuring up tubing followed by rapidly flowing well to tanks. Initial injection rate 0.55 bpm increased to steady 2.1 bpm @ 2100 psi. 11/9/2014 Performed injectectivy test with SLB cement van stepping rates from 1 up to 4 bpm until max pressure of 4000 psi reached, followed by flowing the well to the tanks after reaching max press. Repeated this cycle 5x. Would note during each cycle pressure spiked at—3000 psi whereas injectivity remained stable at lower rates/pressures.WHTP had been stable at 1200 during last weeks testing, however, as of the last cycle WHTP had increased to 1830 psi. See attached SLB treatment report. 11/11/2014 Performed injectivty test following similar format of last step rate test. Establ stable rate of 1.0 bpm @ 1675 psi, increased rate to 2.0 bpm and saw steady pressure increase to max 5300 psi. Estab stable injectivty at 1.4 bpm @ 5350 psi. Attempted to shear sleeve, pressuring up tubing to 7750 psi. Establish stable rate of 1.1 bpm (Cmt van max'd). No indication of shift. Shut down and monitor pressure falloff flatline at 1840 psi. Note: See attached SLB treatment report. 11/12/2014 Pressured up tubing w/LRS pump to 4000 psi, estab stable injectivity 0.7 bpm. Dumped WHIP to tank and continued to flow well for 1.5 hrs thru full open choke, final rate 0.25-0.5 bpm (88 bbls flowed) @ <10 psi FWHTP. Online w/LRS and establish injectivity of 1.9 bpm @ 1800 psi.Repeated pump/flow cycle and let well flow thru full open choke for 4.5 hrs.After initial 1-1/2 hrs flowrate leveled off to 0.25 bpm w/gas @ surface (122 bbls flowed). Secured well for the night. 11/13/2014 Dropped 1.563 non-dissolve ball sized to actuate frac sleeve#2 into tb and chased w/diesel at 2.0 bp 2400 psi, slowly trending up. 41 bbls a trend increased as pressure began building and forced to drop rate to 0.8 bpm 8200 psi. Pumped 244 bbl diesel, no indication of of ball seat/pressure change. 11/18/2014 TRAVEL OVER FROM DEADHORSE, CREW CHANGE OUT DAY, MIRU RESTART IN THE MORNING 11/19/2014 DRIFTED COIL WITH A 1" BALL, DID BOP TEST, GOT SHUT DOWN FOR WEATHER *****RESTART IN THE MORNING**** 11/24/2014 DUG OUT REST OF ASRC EQUIPMENT, GOT THE HEATERS, TRIPLEX AND AIR COMPRESSOR FIRED UP, DID BOP TEST ****RESTART IN THE AM**** 11/25/2014 Perform FCO down to the 1.635" Frac Sleeve with 1 1/2" coil, slick diesel and diesel gel sweeps. Thick frac gel and moderate amounts of proppant seen in returns. 11/26/2014 Attempt unsuccessfully to lift well with N2. Perform second FCO down to 16,250' Unsuccessfully attempt to seat ball @ 17,439'. While POOH, level wind breaks and unit was shut down for repairs. 11/27/2014 DROPPED THE 1.625" NON DISSOLVABLE BALL, PUMPED DOWN THE TUBING TO TRY AND SEAT THE BALL. RIH WITH COIL, DRIFTED RIGHT BY THE SLEEVE AT 16,860'WAS ABLE TO INJECT AT 1 BPM @ 4000 PSI RIG DOWN TURN BACK OVER TO FRAC 11/29/2014 Attempt to shift frac sleeve, pumped total of 92 bbls, rate was 1.4 bpm at 8500 psi, no success, RDMO. 12/4/2014 RIH WITH MODIFIED 1.61" NOZZLE FOR SHIFTING FRAC SLEEVE OPEN AT 16860' RKB, LOAD THE BACKSIDE OF THE COIL WITH 85 BBLS OF 10.9 PPG NaBr/NaCl, TAG UP ON THE SLEEVE AT 16843' CTMD, COME ONLINE WITH SLICK DIESEL DOWN THE BACKSIDE AND THE COIL AT 1.1 BPM TO WALK WHP UP TO 3200 PSI BEFORE SEEING THE PRESSURE DROP OFF TO 1800 PSI AT 1.1 BPM, COME OFFLINE AND PUH TO THE TBG TAIL AT 12,350' CTMD, PERFORM STEP INJECTIVITY TEST DOWN THE BACKSIDE ONLY AS FOLLOWS: .5 BPM © 1275 WHP/1 BPM @ 1600 WHP/1.5 BPM @ 2000 WHP/2 BPM @ 2350 WHP/2.5 BPM @ 2500 WHP/3 BPM @ 2675 WHP/3.5 BPM @ 2600 WHP/4 BPM @ 2730 WHP/4.5 BPM @ 2890 WHP/4.8 BPM @ 2900 WHP WELL LEFT F/P WITH SLICK DIESEL TO 9000' MD (5000 TVD), JOB COMPLETE 12/5/2014 RDMO CTU #5, REPLACE PACKOFFS, PERFORM CHAIN INSPECTION AND STEM 1 ON CTU. JOB COMPLETE 12/8/2014 SLB travel from Deadhorse © 05:30.Arrive location and resume rigging up frontside equipment(missle, treating iron, etc.). Pressure test equipment, complete @ 15:30 at which time determined too late to begin treatment due to 16 hr workday restrictions. Secure equipment, to resume in A.M. 12/9/2014 PUMPED BALL DROP FRAC; PUMP STAGES 4,5,6 & 7. TOTAL OF 390,465#OF 16/20 PROPPANT. DROPPED 1.938" BALL SHIFTING OPEN SLEEVE#7 @ 14,506' RKB, WELL READY TO FRAC STAGE#8. TUBING FREEZE PROTECTED WITH 20 BBLS OF DIESEL, IN PROGRESS. NOTE: TREATMENT REPORT FORTHCOMING 12/12/2014 Performed remaining 4 stages of fracture stimulation per design @ 20 bpm placing 428,936# of 16/20 frac sand (947,520#total, 9 stages). Well flushed to completion, freeze protected w/ 16 bbls of diesel. Note: Will attach SLB treatment report once available. 1/2/2015 B&C CTU #1: DIG OUT UNIT. PERFORM WEEKLY BOP TEST ON BACK DECK. PREPARE TO MILL FRAC SLEEVES IN THE MORNING. 1/3/2015 B&C CTU #1: MILL THROUGH UPPER 4 OF 10 FRAC SLEEVES WITH BAKER 2- 1/8" MOTOR AND 3 BLADE 2.70" JUNK MILL WITH OPTICUT. HANG UP IN 2ND FRAC SLEEVE AND D NIPPLE WHILE POOH. SUSPECT FRAC BALL FRAGMENTS. PLANNING ON A VENTURI RUN PRIOR TO SUBSEQUENT MILL RUNS. IN PROGRESS. 1/4/2015 B&C CTU#1: RECOVER RGE PIECES OF FRAC BALLS WITH BAKER 2.63" VENTURI BASKET. PICTiji -S ATTACHED IN WELLVIEW. PLANNI ON ADDITIONAL VENTURI R PRIOR TO SUBSEQUENT MILL RUNS. PROGRESS. 1/5/2015 B&C CTU#1: RECOVER ADDITIONAL FRAC BALL FRAGMENTS WITH BAKER 2.63"VENTURI BASKET. VENTURI FILTER PACKED WITH METAL FINES. PREPARE TO RESUME MILLING IN THE MORNING. IN PROGRESS. 1/6/2015 B&C CTU #1: MILL THROUGH FRAC SLEEVES#5-7 WITH BAKER 2-1/8" MOTOR AND 3 BLADE 2.70"JUNK MILL WITH OPTICUT. THREE MORE SLEEVES REMAINING. IN PROGRESS. 1/7/2015 B&C CTU #1: MILL THROUGH BOTTOM 3 FRAC SLEEVES WITH BAKER 2-1/8" MOTOR AND 3 BLADE 2.70"JUNK MILL WITH OPTICUT. CIRCULATE SWEEP FROM 18500'. HANG UP IN MULTIPLE SPOTS IN TUBING WHILE POOH. HAD TO PUMP DOWN BACKSIDE OF COIL TO GET MOVING. RIG BACK AND DISCUSS VENTURI RUN PRIOR TO SLICKLINE WORK. 1/8/2015 B&C CTU #1: RECOVER METAL SHAVINGS FROM TUBING WITH BAKER 2.63" VENTURI BASKET. CIRCULATE THROUGH VENTURI FROM SURFACE TO TUBING TAIL, FOCUSING ON GLM AREAS. WELL LEFT SHUT IN AND READY FOR SLICKLINE. 1/9/2015 B&C CTU #1: RIG OFF WELL AFTER LATE JOB. PERFORM WEEKLY BOP TEST ON BACK DECK. MOBILIZE TO 1J PAD. 1/11/2015 DRIFT W/2.67" DOWN TO 12,335' SLM; MEASURED BHP @ 11,521' RKB. SBHP OF 3298 PSI MEASURED. IN PROGRESS. 1/12/2015 SET CSV @ 11521' RKB; PULLED DV'S @ 8618', 6640', &3310' RKB (ALL LATCHES ON DV'S HAVE EROSION FROM FRAC); SET OV @ 8618' &GLV @ 6640' RKB. IN PROGRESS. 1/13/2015 SET GLV @ 3310' RKB; REPLACED DV @ 11,416' RKB; PULLED DV @ 10,199' RKB. (BOTH LATCHES HAD MINOR EROSION FROM FRAC) IN PROGRESS. 1/14/2015 SET DV @ 10,199' RKB; MITT TO 3000 PSI (PASS); PULLED CAT SV @ 11,520' RKB. READY FOR FLOWBACK • RECEIVED • 1 40 76 x%23 71114 SchluS chiumberer AOGCC Transmittal #: 04DEC14-NG02 mberger Drilling & Measurements DATA LOGGED ‘V /2oiK MWD/LWD Log Product Delivery ;v1 K ENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2E-01 Date Dispatched: 4-Dec-14 Job#: 14AKA0056 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: Contents on CD N/A VISION* Resistivil2" MD x x VISION* Resistivil 2"TVD x x VISION* Resistivil 5" MD x x VISION* Resistivil 5"TVD x x VISION* Resistivil 5' MD Mircoscope Resistivity x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Survey: txt,pdf x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.RosoCa7Conocophilips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn: Nathan Green 6ax:5F1-8317 Received By: • 2. ; 4076 25 023 RECEIVED DEC 042014 NADConversion AOGCC Kuparuk River Unit Kuparuk 2E Pad 2E-01 Definitive Survey Report N A D 2 7 26 September, 2014 IIISchlumberger • Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01: 105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01: 105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2E-01 Well Position +NI-8 0.00 usft Northing: 5,944,147.20 usft Latitude: 70°15'30.495 N +EI-W 0.00 usft Easting: 529,971.92 usft Longitude: 149°45'27.903 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.10 usft Wellbore 2E-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 9/15/2014 19.20 80.87 57,574 Design 2E-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.20 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.20 0.00 0.00 180.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 82.30 912.27 2E-01 Svy1 NSG+MSHOT(2E-01) GYD-GC-MS Gyrodata gyrocompassing m/s 9/25/2014 4:39: 968.94 18,590.61 2E-01 Svy2 MWD+GMAG(2E-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/25/2014 4:56: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 27.20 0.00 0.00 27.20 -105.10 0.00 0.00 5,944,147.20 529,971.92 0.00 0.00 UNDEFINED 82.30 0.12 346.37 82.30 -50.00 0.06 -0.01 5,944,147.26 529,971.91 0.22 -0.06 GYD-GC-MS(1) 106.60 0.13 355.95 106.60 -25.70 0.11 -0.02 5,944,147.31 529,971.90 0.10 16"x 42" 169.97 0.17 13.79 169.97 37.67 0.27 0.00 5,944,147.47 529,971.92 0.10 -0.27 GYD-GC-MS(1) 267.63 0.29 17.67 267.63 135.33 0.65 0.11 5,944,147.85 529,972.02 0.12 -0.65 GYD-GC-MS(1) 360.76 1.24 230.29 360.75 228.45 0.23 -0.60 5,944,147.43 529,971.32 1.60 -0.23 GYD-GC-MS(1) 452.70 1.88 226.15 452.66 320.36 -1.45 -2.45 5,944,145.74 529,969.48 0.71 1.45 GYD-GC-MS(1) 544.39 2.83 225.41 544.27 411.97 -4.08 -5.15 5,944,143.10 529,966.79 1.04 4.08 GYD-GC-MS(1) 637.42 5.44 223.67 637.05 504.75 -8.89 -9.83 5,944,138.28 529,962.13 2.81 8.89 GYD-GC-MS(1) 729.79 7.68 229.83 728.81 596.51 -16.04 -17.57 5,944,131.10 529,954.42 2.54 16.04 GYD-GC-MS(1) 819.52 9.86 231.62 817.49 685.19 -24.67 -28.18 5,944,122.42 529,943.85 2.45 24.67 GYD-GC-MS(1) 912.27 12.11 231.93 908.53 776.23 -35.60 -42.06 5,944,111.43 529,930.01 2.43 35.60 GYD-GC-MS(1) 9/26/2014 9:45:40AM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 968.94 12.65 232.03 963.88 831.58 -43.09 -51.63 5,944,103.91 529,920.47 0.95 43.09 MWD+IFR-AK-CAZ-SC(2) 1,061.15 13.77 231.80 1,053.65 921.35 -56.09 -68.22 5,944,090.85 529,903.94 1.22 56.09 MWD+IFR-AK-CAZ-SC(2) 1,155.70 16.06 231.53 1,145.01 1,012.71 -71.18 -87.30 5,944,075.68 529,884.91 2.42 71.18 MWD+IFR-AK-CAZ-SC(2) 1,245.72 17.37 231.58 1,231.22 1,098.92 -87.28 -107.58 5,944,059.50 529,864.70 1.46 87.28 MWD+IFR-AK-CAZ-SC(2) 1,339.70 19.81 230.13 1,320.29 1,187.99 -106.21 -130.80 5,944,040.48 529,841.56 2.64 106.21 MWD+IFR-AK-CAZ-SC(2) 1,432.92 21.09 230.37 1,407.64 1,275.34 -127.03 -155.84 5,944,019.56 529,816.61 1.38 127.03 MWD+IFR-AK-CAZ-SC(2) 1,524.42 21.03 230.51 1,493.03 1,360.73 -147.98 -181.19 5,943,998.52 529,791.34 0.09 147.98 MWD+IFR-AK-CAZ-SC(2) 1,617.89 24.73 229.09 1,579.13 1,446.83 -171.45 -208.92 5,943,974.93 529,763.71 4.00 171.45 MWD+IFR-AK-CAZ-SC(2) 1,710.50 27.43 228.92 1,662.30 1,530.00 -198.16 -239.64 5,943,948.11 529,733.09 2.92 198.16 MWD+IFR-AK-CAZ-SC(2) 1,803.00 29.65 228.87 1,743.55 1,611.25 -227.21 -272.94 5,943,918.92 529,699.92 2.40 227.21 MWD+IFR-AK-CAZ-SC(2) 1,895.81 33.32 229.39 1,822.69 1,690.39 -258.92 -309.59 5,943,887.08 529,663.39 3.97 258.92 MWD+IFR-AK-CAZ-SC(2) 1,988.11 36.46 231.39 1,898.39 1,766.09 -292.54 -350.28 5,943,853.30 529,622.84 3.62 292.54 MWD+IFR-AK-CAZ-SC(2) 2,081.00 40.84 233.55 1,970.92 1,838.62 -327.83 -396.30 5,943,817.83 529,576.96 4.93 327.83 MWD+IFR-AK-CAZ-SC(2) 2,172.88 43.86 233.38 2,038.82 1,906.52 -364.67 -446.03 5,943,780.79 529,527.39 3.29 364.67 MWD+IFR-AK-CAZ-SC(2) 2,266.07 48.03 233.43 2,103.60 1,971.30 -404.59 -499.79 5,943,740.66 529,473.80 4.47 404.59 MWD+IFR-AK-CAZ-SC(2) 2,358.72 51.49 233.04 2,163.44 2,031.14 -446.92 -556.43 5,943,698.11 529,417.33 3.75 446.92 MWD+IFR-AK-CAZ-SC(2) 2,451.27 53.55 232.27 2,219.76 2,087.46 -491.47 -614.81 5,943,653.33 529,359.13 2.32 491.47 MWD+IFR-AK-CAZ-SC(2) 2,542.00 56.53 231.27 2,271.74 2,139.44 -537.49 -673.21 5,943,607.09 529,300.92 3.41 537.49 MWD+IFR-AK-CAZ-SC(2) 2,634.73 59.15 231.16 2,321.09 2,188.79 -586.66 -734.40 5,943,557.68 529,239.94 2.83 586.66 MWD+IFR-AK-CAZ-SC(2) 2,727.57 62.83 230.94 2,366.11 2,233.81 -637.70 -797.53 5,943,506.40 529,177.02 3.97 637.70 MWD+IFR-AK-CAZ-SC(2) 2,819.76 64.69 231.70 2,406.87 2,274.57 -689.37 -862.08 5,943,454.47 529,112.68 2.15 689.37 MWD+IFR-AK-CAZ-SC(2) 2,913.00 64.99 229.96 2,446.51 2,314.21 -742.67 -927.50 5,943,400.92 529,047.48 1.72 742.67 MWD+IFR-AK-CAZ-SC(2) 3,005.29 65.43 228.99 2,485.21 2,352.91 -797.11 -991.19 5,943,346.23 528,984.01 1.07 797.11 MWD+IFR-AK-CAZ-SC(2) 3,095.53 66.12 228.56 2,522.24 2,389.94 -851.35 -1,053.08 5,943,291.75 528,922.34 0.88 851.35 MWD+IFR-AK-CAZ-SC(2) 3,189.54 67.82 228.01 2,559.01 2,426.71 -908.92 -1,117.66 5,943,233.93 528,858.00 1.89 908.92 MWD+IFR-AK-CAZ-SC(2) 3,281.46 67.82 228.08 2,593.72 2,461.42 -965.82 -1,180.96 5,943,176.78 528,794.93 0.07 965.82 MWD+IFR-AK-CAZ-SC(2) 3,375.75 66.78 227.25 2,630.10 2,497.80 -1,024.40 -1,245.26 5,943,117.95 528,730.87 1.37 1,024.40 MWD+IFR-AK-CAZ-SC(2) 3,468.55 65.99 227.20 2,667.28 2,534.98 -1,082.15 -1,307.67 5,943,059.97 528,668.70 0.85 1,082.15 MWD+IFR-AK-CAZ-SC(2) 3,561.77 66.45 228.87 2,704.87 2,572.57 -1,139.18 -1,371.10 5,943,002.68 528,605.50 1.71 1,139.18 MWD+IFR-AK-CAZ-SC(2) 3,654.01 68.08 230.77 2,740.52 2,608.22 -1,194.06 -1,436.10 5,942,947.55 528,540.73 2.59 1,194.06 MWD+IFR-AK-CAZ-SC(2) 3,746.83 66.20 232.25 2,776.58 2,644.28 -1,247.29 -1,503.03 5,942,894.06 528,474.01 2.50 1,247.29 MWD+IFR-AK-CAZ-SC(2) 3,839.66 65.45 232.86 2,814.59 2,682.29 -1,298.79 -1,570.27 5,942,842.31 528,406.99 1.01 1,298.79 MWD+IFR-AK-CAZ-SC(2) 3,931.94 68.89 233.36 2,850.39 2,718.09 -1,349.83 -1,638.28 5,942,791.00 528,339.19 3.76 1,349.83 MWD+IFR-AK-CAZ-SC(2) 4,024.19 68.08 234.02 2,884.22 2,751.92 -1,400.65 -1,707.44 5,942,739.91 528,270.24 1.10 1,400.65 MWD+IFR-AK-CAZ-SC(2) 4,116.12 67.82 233.43 2,918.74 2,786.44 -1,451.06 -1,776.13 5,942,689.23 528,201.76 0.66 1,451.06 MWD+IFR-AK-CAZ-SC(2) 4,209.22 66.78 233.27 2,954.66 2,822.36 -1,502.33 -1,845.04 5,942,637.69 528,133.06 1.13 1,502.33 MWD+IFR-AK-CAZ-SC(2) 4,301.85 66.16 233.23 2,991.64 2,859.34 -1,553.14 -1,913.09 5,942,586.61 528,065.22 0.67 1,553.14 MWD+IFR-AK-CAZ-SC(2) 4,392.57 65.78 232.98 3,028.59 2,896.29 -1,602.89 -1,979.35 5,942,536.61 527,999.16 0.49 1,602.89 MWD+IFR-AK-CAZ-SC(2) 4,485.66 65.97 233.60 3,066.64 2,934.34 -1,653.67 -2,047.46 5,942,485.56 527,931.26 0.64 1,653.67 MWD+IFR-AK-CAZ-SC(2) 4,579.61 65.84 232.96 3,104.99 2,972.69 -1,704.95 -2,116.20 5,942,434.01 527,862.73 0.64 1,704.95 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 3 COMPASS 5000.1 Build 65 • Schlumberger . Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01: 105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 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 4,672.32 65.63 231.92 3,143.09 3,010.79 -1,756.47 -2,183.20 5,942,382.23 527,795.94 1.05 1,756.47 MWD+IFR-AK-CAZ-SC(2) 4,765.03 64.96 230.67 3,181.84 3,049.54 -1,809.13 -2,248.93 5,942,329.31 527,730.43 1.42 1,809.13 MWD+IFR-AK-CAZ-SC(2) 4,855.65 65.16 230.17 3,220.05 3,087.75 -1,861.49 -2,312.26 5,942,276.71 527,667.32 0.55 1,861.49 MWD+IFR-AK-CAZ-SC(2) 4,869.57 65.11 230.15 3,225.91 3,093.61 -1,869.58 -2,321.96 5,942,268.58 527,657.65 0.38 1,869.58 MWD+IFR-AK-CAZ-SC(2) 4,939.70 65.67 230.50 3,255.11 3,122.81 -1,910.28 -2,371.03 5,942,227.69 527,608.74 0.92 1,910.28 10-314"x 13-1/2" 4,959.62 65.83 230.60 3,263.29 3,130.99 -1,921.82 -2,385.06 5,942,216.09 527,594.77 0.92 1,921.82 MWD+IFR-AK-CAZ-SC(2) 5,052.34 67.44 230.66 3,300.06 3,167.76 -1,975.81 -2,450.86 5,942,161.85 527,529.19 1.74 1,975.81 MWD+IFR-AK-CAZ-SC(2) 5,146.51 67.94 231.04 3,335.81 3,203.51 -2,030.82 -2,518.42 5,942,106.58 527,461.85 0.65 2,030.82 MWD+IFR-AK-CAZ-SC(2) 5,238.93 67.62 231.91 3,370.76 3,238.46 -2,084.11 -2,585.35 5,942,053.03 527,395.14 0.94 2,084.11 MWD+IFR-AK-CAZ-SC(2) 5,330.93 66.42 229.85 3,406.68 3,274.38 -2,137.54 -2,651.06 5,941,999.34 527,329.65 2.44 2,137.54 MWD+IFR-AK-CAZ-SC(2) 5,421.69 64.94 227.42 3,444.06 3,311.76 -2,192.18 -2,713.13 5,941,944.46 527,267.80 2.93 2,192.18 MWD+IFR-AK-CAZ-SC(2) 5,514.43 64.90 227.06 3,483.37 3,351.07 -2,249.21 -2,774.80 5,941,887.19 527,206.37 0.35 2,249.21 MWD+IFR-AK-CAZ-SC(2) 5,608.06 64.79 227.96 3,523.17 3,390.87 -2,306,45 -2,837.30 5,941,829.71 527,144.11 0.88 2,306.45 MWD+IFR-AK-CAZ-SC(2) 5,699.60 64.79 229.93 3,562.17 3,429.87 -2,360.84 -2,899.74 5,941,775.07 527,081.88 1.95 2,360.84 MWD+IFR-AK-CAZ-SC(2) 5,793.29 64.76 232.01 3,602.10 3,469.80 -2,414.21 -2,965.58 5,941,721.45 527,016.27 2.01 2,414.21 MWD+IFR-AK-CAZ-SC(2) 5,884.77 64.80 233.84 3,641.08 3,508.78 -2,464.10 -3,031.61 5,941,671.30 526,950.45 1.81 2,464.10 MWD+IFR-AK-CAZ-SC(2) 5,977.75 64.57 234.42 3,680.84 3,548.54 -2,513.35 -3,099.72 5,941,621.78 526,882.54 0.62 2,513.35 MWD+IFR-AK-CAZ-SC(2) 6,071.02 64.78 234.34 3,720.73 3,588.43 -2,562.45 -3,168.25 5,941,572.42 526,814.21 0.24 2,562.45 MWD+IFR-AK-CAZ-SC(2) 6,163.31 64.64 234.53 3,760.16 3,627.86 -2,610.99 -3,236.13 5,941,523.62 526,746.53 0.24 2,610.99 MWD+IFR-AK-CAZ-SC(2) 6,255.40 64.64 234.58 3,799.60 3,667.30 -2,659.24 -3,303.92 5,941,475.09 526,678.94 0.05 2,659.24 MVVD+IFR-AK-CAZ-SC(2) 6,348.83 64.62 235.10 3,839.64 3,707.34 -2,707.86 -3,372.94 5,941,426.21 526,610.12 0.50 2,707.86 MWD+IFR-AK-CAZ-SC(2) 6,441.54 64.62 235.56 3,879.37 3,747.07 -2,755.51 -3,441.83 5,941,378.29 526,541.43 0.45 2,755.51 MWD+IFR-AK-CAZ-SC(2) 6,534.39 64.62 235.71 3,919.17 3,786.87 -2,802.86 -3,511.07 5,941,330.67 526,472.38 0.15 2,802.86 MWD+IFR-AK-CAZ-SC(2) 6,627.16 64.68 235.79 3,958.89 3,826.59 -2,850.04 -3,580.37 5,941,283.22 526,403.27 0.10 2,850.04 MWD+IFR-AK-CAZ-SC(2) 6,720.81 64.64 235.11 3,998.97 3,866.67 -2,898.04 -3,650.08 5,941,234.94 526,333.76 0.66 2,898.04 MWD+IFR-AK-CAZ-SC(2) 6,811.76 64.65 234.17 4,037.92 3,905.62 -2,945.61 -3,717.11 5,941,187.12 526,266.93 0.93 2,945.61 MWD+IFR-AK-CAZ-SC(2) 6,904.52 64.64 233.55 4,077.64 3,945.34 -2,995.04 -3,784.80 5,941,137.42 526,199.44 0.60 2,995.04 MWD+IFR-AK-CAZ-SC(2) 6,997.88 64.62 232.06 4,117.64 3,985.34 -3,046.04 -3,852.00 5,941,086.16 526,132.46 1.44 3,046.04 MWD+IFR-AK-CAZ-SC(2) 7,090.24 64.26 230.46 4,157.50 4,025.20 -3,098.17 -3,916.99 5,941,033.77 526,067.68 1.61 3,098.17 MWD+IFR-AK-CAZ-SC(2) 7,183.95 64.13 229.60 4,198.29 4,065.99 -3,152.37 -3,981.64 5,940,979.33 526,003.25 0.84 3,152.37 MWD+IFR-AK-CAZ-SC(2) 7,274.33 64.37 228.72 4,237.55 4,105.25 -3,205.60 -4,043.23 5,940,925.85 525,941.88 0.92 3,205.60 MWD+IFR-AK-CAZ-SC(2) 7,367.45 64.55 228.62 4,277.70 4,145.40 -3,261.09 -4,106.32 5,940,870.12 525,879.02 0.22 3,261.09 MWD+IFR-AK-CAZ-SC(2) 7,462.22 64.66 229.02 4,318.35 4,186.05 -3,317.46 -4,170.75 5,940,813.50 525,814.81 0.40 3,317.46 MWD+IFR-AK-CAZ-SC(2) 7,554.35 64.96 229.48 4,357.56 4,225.26 -3,371.88 -4,233.91 5,940,758.84 525,751.88 0.56 3,371.88 MWD+IFR-AK-CAZ-SC(2) 7,647.05 65.19 229.89 4,396.62 4,264.32 -3,426.27 -4,298.01 5,940,704.20 525,688.00 0.47 3,426.27 MWD+IFR-AK-CAZ-SC(2) 7,737.49 65.12 231.03 4,434.63 4,302.33 -3,478.51 -4,361.30 5,940,651.71 525,624.93 1.15 3,478.51 MWD+IFR-AK-CAZ-SC(2) 7,828.15 65.18 232.01 4,472.73 4,340.43 -3,529.70 -4,425.70 5,940,600.27 525,560.74 0.98 3,529.70 MWD+IFR-AK-CAZ-SC(2) 7,922.94 65.08 232.71 4,512.59 4,380.29 -3,582.22 -4,493.80 5,940,547.48 525,492.86 0.68 3,582.22 MVVD+IFR-AK-CAZ-SC(2) 8,015.71 65.01 232.96 4,551.73 4,419.43 -3,633.03 -4,560.83 5,940,496.41 525,426.04 0.26 3,633.03 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 4 COMPASS 5000.1 Build 65 • SchlumbergerIII Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section • (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,108.53 65.15 233.64 4,590.84 4,458.54 -3,683.34 -4,628.32 5,940,445.84 525,358.76 0.68 3,683.34 MWD+IFR-AK-CAZ-SC(2) 8,201.55 65.09 233.68 4,629.98 4,497.68 -3,733.34 -4,696.29 5,940,395.57 525,290.99 0.08 3,733.34 MWD+IFR-AK-CAZ-SC(2) 8,295.16 65.05 233.36 4,669.43 4,537.13 -3,783.81 -4,764.55 5,940,344.83 525,222.94 0.31 3,783.81 MWD+IFR-AK-CAZ-SC(2) 8,386.86 65.06 233.51 4,708.11 4,575.81 -3,833.34 -4,831.33 5,940,295.04 525,156.36 0.15 3,833.34 MWD+IFR-AK-CAZ-SC(2) 8,480.44 65.12 233.74 4,747.52 4,615.22 -3,883.68 -4,899.66 5,940,244.44 525,088.24 0.23 3,883.68 MWD+IFR-AK-CAZ-SC(2) 8,572.33 65.22 233.50 4,786.11 4,653.81 -3,933.15 -4,966.81 5,940,194.71 525,021.30 0.26 3,933.15 MWD+IFR-AK-CAZ-SC(2) 8,666.54 65.16 233.50 4,825.64 4,693.34 -3,984.01 -5,035.55 5,940,143.58 524,952.77 0.06 3,984.01 MWD+IFR-AK-CAZ-SC(2) 8,755.96 65.15 232.81 4,863.21 4,730.91 -4,032.67 -5,100.48 5,940,094.67 524,888.03 0.70 4,032.67 MWD+IFR-AK-CAZ-SC(2) 8,850.09 65.16 231.94 4,902.77 4,770.47 -4,084.82 -5,168.14 5,940,042.26 524,820.59 0.84 4,084.82 MWD+IFR-AK-CAZ-SC(2) 8,942.14 65.15 231.08 4,941.44 4,809.14 -4,136.80 -5,233.52 5,939,990.01 524,755.43 0.85 4,136.80 MWD+IFR-AK-CAZ-SC(2) 9,035.15 65.05 230.95 4,980.60 4,848.30 -4,189.88 -5,299.09 5,939,936.68 524,690.07 0.17 4,189.88 MWD+IFR-AK-CAZ-SC(2) 9,127.23 65.09 230.49 5,019.42 4,887.12 -4,242.74 -5,363.73 5,939,883.57 524,625.65 0.46 4,242.74 MWD+IFR-AK-CAZ-SC(2) 9,221.17 65.11 229.97 5,058.97 4,926.67 -4,297.25 -5,429.22 5,939,828.81 524,560.38 0.50 4,297.25 MWD+IFR-AK-CAZ-SC(2) 9,312.93 65.51 229.15 5,097.30 4,965.00 -4,351.33 -5,492.67 5,939,774.48 524,497.15 0.92 4,351.33 MWD+IFR-AK-CAZ-SC(2) 9,405.58 65.69 229.53 5,135.57 5,003.27 -4,406.31 -5,556.68 5,939,719.25 524,433.37 0.42 4,406.31 MWD+IFR-AK-CAZ-SC(2) 9,497.49 65.81 230.36 5,173.32 5,041.02 -4,460.23 -5,620.82 5,939,665.08 524,369.45 0.83 4,460.23 MWD+IFR-AK-CAZ-SC(2) 9,590.87 65.72 231.45 5,211.65 5,079.35 -4,513.93 -5,686.90 5,939,611.13 524,303.59 1.07 4,513.93 MWD+IFR-AK-CAZ-SC(2) 9,683.59 65.68 231.89 5,249.81 5,117.51 -4,566.34 -5,753.19 5,939,558.46 524,237.52 0.43 4,566.34 MWD+IFR-AK-CAZ-SC(2) 9,775.20 65.90 232.40 5,287.38 5,155.08 -4,617.61 -5,819.16 5,939,506.93 524,171.76 0.56 4,617.61 MWD+IFR-AK-CAZ-SC(2) 9,867.85 66.06 232.85 5,325.09 5,192.79 -4,668.98 -5,886.41 5,939,455.30 524,104.72 0.48 4,668.98 MWD+IFR-AK-CAZ-SC(2) 9,961.14 66.16 231.58 5,362.87 5,230.57 -4,721.24 -5,953.82 5,939,402.77 524,037.52 1.25 4,721.24 MWD+IFR-AK-CAZ-SC(2) 10,051.54 66.19 230.79 5,399.39 5,267.09 -4,773.07 -6,018.26 5,939,350.69 523,973.30 0.80 4,773.07 MWD+IFR-AK-CAZ-SC(2) 10,145.71 66.28 231.55 5,437.34 5,305.04 -4,827.11 -6,085.40 5,939,296.39 523,906.38 0.74 4,827.11 MWD+IFR-AK-CAZ-SC(2) 10,236.74 66.19 232.36 5,474.02 5,341.72 -4,878.46 -6,151.00 5,939,244.79 523,840.99 0.82 4,878.46 MWD+IFR-AK-CAZ-SC(2) 10,330.63 66.23 231.82 5,511.90 5,379.60 -4,931.24 -6,218.79 5,939,191.74 523,773.42 0.53 4,931.24 MWD+IFR-AK-CAZ-SC(2) 10,423.27 65.62 231.21 5,549.69 5,417.39 -4,983.88 -6,285.00 5,939,138.85 523,707.43 0.89 4,983.88 MWD+IFR-AK-CAZ-SC(2) 10,514.58 65.14 230.74 5,587.73 5,455.43 -5,036.14 -6,349.48 5,939,086.33 523,643.16 0.70 5,036.14 MWD+IFR-AK-CAZ-SC(2) 10,609.10 65.41 229.58 5,627.26 5,494.96 -5,091.15 -6,415.40 5,939,031.07 523,577.46 1.15 5,091.15 MWD+IFR-AK-CAZ-SC(2) 10,699.26 65.28 228.87 5,664.87 5,532.57 -5,144.66 -6,477.45 5,938,977.32 523,515.63 0.73 5,144.66 MWD+IFR-AK-CAZ-SC(2) 10,794.28 65.34 228.06 5,704.57 5,572.27 -5,201.90 -6,542.08 5,938,919.82 523,451.24 0.78 5,201.90 MWD+IFR-AK-CAZ-SC(2) 10,886.37 65.44 225.53 5,742.92 5,610.62 -5,259.22 -6,603.10 5,938,862.27 523,390.46 2.50 5,259.22 MWD+IFR-AK-CAZ-SC(2) 10,977.51 65.33 222.76 5,780.89 5,648.59 -5,318.67 -6,660.80 5,938,802.60 523,333.00 2.77 5,318.67 MWD+IFR-AK-CAZ-SC(2) 11,071.39 65.73 220.11 5,819.78 5,687.48 -5,382.72 -6,717.34 5,938,738.33 523,276.72 2.60 5,382.72 MWD+IFR-AK-CAZ-SC(2) 11,162.31 66.81 216.72 5,856.38 5,724.08 -5,447.93 -6,769.04 5,938,672.92 523,225.29 3.61 5,447.93 MWD+IFR-AK-CAZ-SC(2) 11,255.99 69.05 213.09 5,891.58 5,759.28 -5,519.12 -6,818.68 5,938,601.54 523,175.93 4.31 5,519.12 MWD+IFR-AK-CAZ-SC(2) 11,348.83 71.53 210.29 5,922.90 5,790.60 -5,593.48 -6,864.57 5,938,527.00 523,130.34 3.90 5,593.48 MWD+IFR-AK-CAZ-SC(2) 11,440.90 74.26 209.73 5,949.98 5,817.68 -5,669.68 -6,908.58 5,938,450.64 523,086.64 3.02 5,669.68 MWD+IFR-AK-CAZ-SC(2) 11,533.26 76.88 209.20 5,972.99 5,840.69 -5,747.55 -6,952.57 5,938,372.60 523,042.97 2.89 5,747.55 MWD+IFR-AK-CAZ-SC(2) 11,625.27 78.20 208.64 5,992.84 5,860.54 -5,826.19 -6,996.01 5,938,293.80 522,999.84 1.55 5,826.19 MWD+IFR-AK-CAZ-SC(2) 11,719.97 78.55 206.16 6,011.93 5,879.63 -5,908.53 -7,038.70 5,938,211.29 522,957.49 2.59 5,908.53 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 5 COMPASS 5000.1 Build 65 • Schlumberger . Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01: 105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey I 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 11,811.21 78.26 204.63 6,030.27 5,897.97 -5,989.27 -7,077.03 5,938,130.41 522,919.49 1.67 5,989.27 MWD+IFR-AK-CAZ-SC(2) 11,905.50 77.24 203.30 6,050.27 5,917.97 -6,073.47 -7,114.45 5,938,046.07 522,882.40 1.75 6,073.47 MWD+IFR-AK-CAZ-SC(2) 11,997.63 76.96 200.88 6,070.84 5,938.54 -6,156.67 -7,148.22 5,937,962.74 522,848.96 2.58 6,156.67 MWD+IFR-AK-CAZ-SC(2) 12,090.29 76.40 199.58 6,092.19 5,959.89 -6,241.27 -7,179.40 5,937,878.03 522,818.12 1.49 6,241.27 MWD+IFR-AK-CAZ-SC(2) 12,184.40 78.38 197.58 6,112.74 5,980.44 -6,328.32 -7,208.66 5,937,790.87 522,789.22 2.95 6,328.32 MWD+IFR-AK-CAZ-SC(2) 12,275.51 81.43 195.44 6,128.71 5,996.41 -6,414.31 -7,234.14 5,937,704.79 522,764.08 4.07 6,414.31 MWD+IFR-AK-CAZ-SC(2) 12,368.61 83.97 192.11 6,140.54 6,008.24 -6,503.98 -7,256.11 5,937,615.04 522,742.47 4.48 6,503.98 MWD+IFR-AK-CAZ-SC(2) 12,461.58 84.42 189.67 6,149.95 6,017.65 -6,594.80 -7,273.58 5,937,524.16 522,725.36 2.66 6,594.80 M1ND+IFR-AK-CAZ-SC(2) 12,505.86 83.36 189.18 6,154.66 6,022.36 -6,638.23 -7,280.79 5,937,480.71 522,718.32 2.63 6,638.23 MWD+IFR-AK-CAZ-SC(2) 12,560.27 83.66 187.55 6,160.81 6,028.51 -6,691.72 -7,288.66 5,937,427.20 522,710.67 3.02 6,691.72 7-5/8"x 9-7/8" 12,591.24 83.84 186.63 6,164.18 6,031.88 -6,722.27 -7,292.46 5,937,396.63 522,706.99 3.02 6,722.27 MWD+IFR-AK-CAZ-SC(2) 12,629.75 84.98 184.32 6,167.93 6,035.63 -6,760.41 -7,296.12 5,937,358.48 522,703.49 6.66 6,760.41 MVVD+IFR-AK-CAZ-SC(2) 12,679.03 87.40 183.52 6,171.20 6,038.90 -6,809.47 -7,299.48 5,937,309.42 522,700.32 5.17 6,809.47 MWD+IFR-AK-CAZ-SC(2) 12,724.64 89.62 182,07 6,172.39 6,040.09 -6,855.00 -7,301.70 5,937,263.87 522,698.28 5.81 6,855.00 MWD+IFR-AK-CAZ-SC(2) 12,816.07 90.90 181.48 6,171.98 6,039.68 -6,946.39 -7,304.53 5,937,172.49 522,695.81 1.54 6,946.39 MWD+IFR-AK-CAZ-SC(2) 12,911.54 91.55 180.78 6,169.93 6,037.63 -7,041.81 -7,306.41 5,937,077.06 522,694.31 1.00 7,041.81 MVVD+IFR-AK-CAZ-SC(2) 13,006.41 91.99 180.22 6,167.00 6,034.70 -7,136.64 -7,307.24 5,936,982.25 522,693.86 0.75 7,136.64 MWD+IFR-AK-CAZ-SC(2) 13,101.12 91.51 180.71 6,164.11 6,031.81 -7,231.30 -7,308.01 5,936,887.60 522,693.47 0.72 7,231.30 MWD+IFR-AK-CAZ-SC(2) 13,196.24 91.34 181.28 6,161.75 6,029.45 -7,326.37 -7,309.66 5,936,792.52 522,692.20 0.63 7,326.37 MWD+IFR-AK-CAZ-SC(2) 13,291.11 90.89 181.55 6,159.90 6,027.60 -7,421.20 -7,312.00 5,936,697.70 522,690.23 0.55 7,421.20 MWD+IFR-AK-CAZ-SC(2) 13,385.67 90.04 181.02 6,159.13 6,026.83 -7,515.73 -7,314.12 5,936,603.17 522,688.49 1.06 7,515.73 MWD+IFR-AK-CAZ-SC(2) 13,480.59 88.10 180.83 6,160.67 6,028.37 -7,610.62 -7,315.66 5,936,508.28 522,687.33 2.05 7,610.62 MWD+IFR-AK-CAZ-SC(2) 13,574.63 88.19 180.87 6,163.72 6,031.42 -7,704.60 -7,317.05 5,936,414.31 522,686.31 0.10 7,704.60 MWD+IFR-AK-CAZ-SC(2) 13,670.16 87.29 181.79 6,167.48 6,035.18 -7,800.03 -7,319.27 5,936,318.88 522,684.48 1.35 7,800.03 MWD+IFR-AK-CAZ-SC(2) 13,765.15 86.90 182.48 6,172.30 6,040.00 -7,894.83 -7,322.80 5,936,224.08 522,681.32 0.83 7,894.83 MWD+IFR-AK-CAZ-SC(2) 13,859.77 88.51 182.83 6,176.09 6,043.79 -7,989.27 -7,327.18 5,936,129.63 522,677.32 1.74 7,989.27 MWD+IFR-AK-CAZ-SC(2) 13,953.90 87.71 183.51 6,179.19 6,046.89 -8,083.20 -7,332.38 5,936,035.69 522,672.49 1.12 8,083.20 MWD+IFR-AK-CAZ-SC(2) 14,048.87 88.18 182.73 6,182.60 6,050.30 -8,177.97 -7,337.55 5,935,940.91 522,667.70 0.96 8,177.97 MWD+IFR-AK-CAZ-SC(2) 14,143.49 88.56 182.91 6,185.29 6,052.99 -8,272.44 -7,342.20 5,935,846.43 522,663.42 0.44 8,272.44 MWD+IFR-AK-CAZ-SC(2) 14,237.01 88.53 183.32 6,187.66 6,055.36 -8,365.79 -7,347.28 5,935,753.07 522,658.72 0.44 8,365.79 MWD+IFR-AK-CAZ-SC(2) 14,331.75 88.43 182.50 6,190.18 6,057.88 -8,460.37 -7,352.09 5,935,658.48 522,654.29 0.87 8,460.37 MWD+IFR-AK-CAZ-SC(2) 14,427.36 88.87 181.93 6,192.43 6,060.13 -8,555.88 -7,355.78 5,935,562.96 522,650.97 0.75 8,555.88 MWD+IFR-AK-CAZ-SC(2) 14,521.73 88.21 183.33 6,194.83 6,062.53 -8,650.12 -7,360.11 5,935,468.72 522,647.02 1.64 8,650.12 MWD+IFR-AK-CAZ-SC(2) 14,617.01 89.04 182.89 6,197.12 6,064.82 -8,745.23 -7,365.28 5,935,373.60 522,642.23 0.99 8,745.23 MWD+IFR-AK-CAZ-SC(2) 14,711.17 88.46 182.17 6,199.17 6,066.87 -8,839.27 -7,369.43 5,935,279.55 522,638.45 0.98 8,839.27 MWD+IFR-AK-CAZ-SC(2) 14,805.41 88.73 181.94 6,201.49 6,069.19 -8,933.43 -7,372.81 5,935,185.39 522,635.45 0.38 8,933.43 MWD+IFR-AK-CAZ-SC(2) 14,898.98 89.01 181.73 6,203.33 6,071.03 -9,026.93 -7,375.81 5,935,091.89 522,632.82 0.37 9,026.93 MWD+IFR-AK-CAZ-SC(2) 14,994.56 88.84 181.38 6,205.12 6,072.82 -9,122.46 -7,378.40 5,934,996.36 522,630.61 0.41 9,122.46 MWD+IFR-AK-CAZ-SC(2) 15,090.36 87.47 181.16 6,208.21 6,075.91 -9,218.18 -7,380.52 5,934,900.64 522,628.87 1.45 9,218.18 MWD+IFR-AK-CAZ-SC(2) 9/26!2014 9:45:40AM Page 6 COMPASS 5000.1 Build 65 • Schlumberger411 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,185.59 86.95 181.18 6,212.84 6,080.54 -9,313.28 -7,382.47 5,934,805.54 522,627.31 0.55 9,313.28 MWD+IFR-AK-CAZ-SC(2) 15,280.69 87.60 180.98 6,217.36 6,085.06 -9,408.25 -7,384.26 5,934,710.57 522,625.89 0.72 9,408.25 MWD+IFR-AK-CAZ-SC(2) 15,375.89 88.58 180.34 6,220.54 6,088.24 -9,503.39 -7,385.35 5,934,615.44 522,625.18 1.23 9,503.39 MWD+IFR-AK-CAZ-SC(2) 15,469.15 91.33 179.33 6,220.61 6,088.31 -9,596.64 -7,385.08 5,934,522.20 522,625.82 3.14 9,596.64 MWD+IFR-AK-CAZ-SC(2) 15,563.95 90.90 180.08 6,218.77 6,086.47 -9,691.42 -7,384.60 5,934,427.43 522,626.68 0.91 9,691.42 MVVD+IFR-AK-CAZ-SC(2) 15,660.31 90.00 181.33 6,218.01 6,085.71 -9,787.77 -7,385.78 5,934,331.09 522,625.88 1.60 9,787.77 MWD+IFR-AK-CAZ-SC(2) 15,753.64 89.66 180.31 6,218.29 6,085.99 -9,881.09 -7,387.12 5,934,237.77 522,624.91 1.15 9,881.09 MWD+IFR-AK-CAZ-SC(2) 15,848.11 90.35 179.83 6,218.28 6,085.98 -9,975.56 -7,387.23 5,934,143.31 522,625.17 0.89 9,975.56 MWD+IFR-AK-CAZ-SC(2) 15,943.86 90.18 180.00 6,217.83 6,085.53 -10,071.31 -7,387.09 5,934,047.58 522,625.70 0.25 10,071.31 MWD+IFR-AK-CAZ-SC(2) 16,038.11 88.91 181.15 6,218.58 6,086.28 -10,165.54 -7,388.04 5,933,953.34 522,625.13 1.82 10,165.54 MWD+IFR-AK-CAZ-SC(2) 16,133.12 88.18 180.47 6,221.00 6,088.70 -10,260.51 -7,389.38 5,933,858.38 522,624.16 1.05 10,260.51 MVVD+IFR-AK-CAZ-SC(2) 16,226.50 87.36 181.03 6,224.63 6,092.33 -10,353.81 -7,390.60 5,933,765.09 522,623.31 1.06 10,353.81 MWD+IFR-AK-CAZ-SC(2) 16,320.83 87.29 181.00 6,229.03 6,096.73 -10,448.03 -7,392.27 5,933,670.88 522,622.02 0.08 10,448.03 MWD+IFR-AK-CAZ-SC(2) 16,414.45 88.19 182.70 6,232.72 6,100.42 -10,541.52 -7,395.29 5,933,577.38 522,619.37 2.05 10,541.52 MWD+IFR-AK-CAZ-SC(2) 16,507.28 88.87 185.06 6,235.11 6,102.81 -10,634.10 -7,401.57 5,933,484.79 522,613.46 2.64 10,634.10 MWD+IFR-AK-CAZ-SC(2) 16,602.94 89.04 186.14 6,236.85 6,104.55 -10,729.29 -7,410.90 5,933,389.57 522,604.51 1.14 10,729.29 MWD+IFR-AK-CAZ-SC(2) 16,697.61 90.24 186.43 6,237.45 6,105.15 -10,823.38 -7,421.27 5,933,295.44 522,594.52 1.30 10,823.38 MVVD+IFR-AK-CAZ-SC(2) 16,791.90 90.11 185.85 6,237.16 6,104.86 -10,917.13 -7,431.35 5,933,201.67 522,584.81 0.63 10,917.13 MWD+IFR-AK-CAZ-SC(2) 16,886.48 88.91 185.77 6,237.97 6,105.67 -11,011.22 -7,440.92 5,933,107.55 522,575.61 1.27 11,011.22 MWD+IFR-AK-CAZ-SC(2) 16,980.86 88.43 185.23 6,240.16 6,107.86 -11,105.14 -7,449.97 5,933,013.60 522,566.94 0.77 11,105.14 MWD+IFR-AK-CAZ-SC(2) 17,074.50 88.32 184.80 6,242.81 6,110.51 -11,198.38 -7,458.15 5,932,920.34 522,559.13 0.47 11,198.38 MWD+IFR-AK-CAZ-SC(2) 17,169.47 89.15 184.22 6,244.91 6,112.61 -11,293.03 -7,465.62 5,932,825.67 522,552.04 1.07 11,293.03 MWD+IFR-AK-CAZ-SC(2) 17,263.82 89.15 184.42 6,246.31 6,114.01 -11,387.11 -7,472.72 5,932,731.58 522,545.31 0.21 11,387.11 MWD+IFR-AK-CAZ-SC(2) 17,359.41 88.56 183.38 6,248.22 6,115.92 -11,482.45 -7,479.22 5,932,636.21 522,539.19 1.25 11,482.45 MWD+IFR-AK-CAZ-SC(2) 17,455.33 88.32 182.06 6,250.83 6,118.53 -11,578.23 -7,483.77 5,932,540.43 522,535.02 1.40 11,578.23 MWD+IFR-AK-CAZ-SC(2) 17,550.54 88.49 182.08 6,253.48 6,121.18 -11,673.34 -7,487.21 5,932,445.32 522,531.96 0.18 11,673.34 MWD+IFR-AK-CAZ-SC(2) 17,644.99 88.94 181.80 6,255.60 6,123.30 -11,767.71 -7,490.41 5,932,350.94 522,529.14 0.56 11,767.71 MWD+IFR-AK-CAZ-SC(2) 17,740.48 89.04 182.67 6,257.28 6,124.98 -11,863.11 -7,494.13 5,932,255.53 522,525.80 0.92 11,863.11 MWD+IFR-AK-CAZ-SC(2) 17,834.47 89.04 183.58 6,258.86 6,126.56 -11,956.95 -7,499.25 5,932,161.69 522,521.05 0.97 11,956.95 MWD+IFR-AK-CAZ-SC(2) 17,929.21 89.01 182.59 6,260.47 6,128.17 -12,051.54 -7,504.35 5,932,067.09 522,516.33 1.05 12,051.54 MWD+IFR-AK-CAZ-SC(2) 18,023.30 89.63 184.51 6,261.59 6,129.29 -12,145.43 -7,510.18 5,931,973.18 522,510.88 2.14 12,145.43 MWD+IFR-AK-CAZ-SC(2) 18,118.61 90.00 185.57 6,261.89 6,129.59 -12,240.37 -7,518.55 5,931,878.22 522,502.88 1.18 12,240.37 MWD+IFR-AK-CAZ-SC(2) 18,212.69 89.97 182.60 6,261.92 6,129.62 -12,334.20 -7,525.25 5,931,784.37 522,496.56 3.16 12,334.20 MWD+IFR-AK-CAZ-SC(2) 18,307.18 90.59 181.13 6,261.46 6,129.16 -12,428.64 -7,528.33 5,931,689.93 522,493.86 1.69 12,428.64 MWD+IFR-AK-CAZ-SC(2) 18,400.48 90.53 179.93 6,260.54 6,128.24 -12,521.93 -7,529.19 5,931,596.65 522,493.37 1.29 12,521.93 MWD+IFR-AK-CAZ-SC(2) 18,496.70 88.67 179.05 6,261.22 6,128.92 -12,618.14 -7,528.33 5,931,500.45 522,494.61 2.14 12,618.14 MWD+IFR-AK-CAZ-SC(2) 18,590.61 87.84 179.42 6,264.08 6,131.78 -12,712.00 -7,527.08 5,931,406.61 522,496.23 0.97 12,712.00 MWD+IFR-AK-CAZ-SC(2) 18,650.00 87.84 179.42 6,266.31 6,134.01 -12,771.34 -7,526.48 5,931,347.28 522,497.07 0.00 12,771.34 4-1/2"x 6-3/4" 18,670.00 87,84 179.42 6,267.07 6,134.77 -12,791.33 -7,526.28 5,931,327.29 522,497.35 0.00 12,791.33 PROJECTED to TD 9/26/2014 9:45.40AM Page 7 COMPASS 5000.1 Build 65 0 • CO 0O y 0 Nb L M 0 ii O bo li wD1^O V Q o 0 >,0% 0Ng N M d C N M 2 C▪ $ _ 6a0tu � wio o s as .z .. o00 H .c d w 0 > o m a U t0 C Lc U ; 0 O v' moi: L' z E O p ^ O 4.. U) +- 0 V/ it O N C a) to 8 y w O L N (3j O d O U o 0 ami 03 o d > ;i o$ , m03 W = N d 1 • U L 'a a) v Y D N n LL. y (4 a) 0 0 a) t a ' oao 0 CD RI Q w ru 0 ai J U (0 22 o Q N CL a-. C N U Pyr A € � \: / 333 \A'est ievenih Avenue Go` ERNoR St AN pARNF.LI. Ancnoroge, Alaska 99501-3579 Mom: 907.279. 453 c 90;.2- .. Adam Klem Sr. Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-01 Sundry Number: 314-568 Dear Mr. Klem: 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, � l Cathy P. qerster Chair DATED this 7- ay of October, 2014. Encl. STATE OF ALASKA RECEIVED I' ALASKA OIL AND GAS CONSERVATION COMMISSION • 001A APPLICATION FOR SUNDRY APPROVALS OCT 21 2014 t01,3)pf 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Chan r am ""'" Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate �� Alter casing r Other: r--- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r7. 214-076-0 ' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23516-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ‘o 4.�s4 Will planned perforations require spacing exception? Yes r No I✓ %OW 2E-01 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25658,25665,25666,392364 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 18670 - 6267 ' 18670' • 6267' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107' 107' SURFACE 4912 10.75 4939' 3255' INTERMEDIATE 12534 7.625 12560' 6161' LINER 6281 4.5 18650' 6266' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): not perforated • not perforated 3.5 L-80 12392 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PRODUCTION PACKER MD=11493 TVD=5963 PACKER-HRD ZXP LINER TOP PACKER MD=12369 TVD=6141 NIPPLE-CAMCO DS NIPPLE MD=498 TVD=497, 12.Attachments: Description Summary of Proposal wi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/24/2014 Oil Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ E GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam.Klem(ciconocophillips.com Printed Name �// Adam Klem Title: Sr. Completions Engineer Signature Phone:263-4529 Date ��Aao/j/y Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness %k4.^' SIDS Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No 137 _I Subsequent Form Required: /U — D aei- APPROVED BY / Approved by: 2(49.-2,4-'"3 -4----- COMMISSIONER THE COMMISSION Date: /C, - 2 V -/ `1proved application is valid tor 12 months trom the date of approval. -pa, 10/74 Form 10-403(Revised 10/2012) ORIGINAL Submit Form and Attachments in Duplicate vi i o /Z3/ ;4- RBC MS OCT 2 7 2011 • 2E-01 Sundry Application 2E-01 was drilled and the production liner casing was landed on 9/20/14. (A schematic of the completion is attached). The well will has an approximately 5,800' horizontal placed in the A sand completed with a 4.5" liner with a pressure activated sleeve at the toe and 10 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 1000 bpd in 2014 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Bermuda sand 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 17 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. 15,034 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 648bb1 DataFrac stage (25# linear gel, WF130) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. Stage 1 • 410 bbls YF130ST Pad • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 1 Stage 2 • 410 bbls YF130ST Pad AK • • • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/6 ppa 16/20 Carbolite • Drop ball 2 Stage 3 • 410 bbls YF130ST Pad • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 3 Stage 4 • 410 bbls YF130ST Pad • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 4 Stage 5 • 410 bbls YF130ST Pad • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 5 Stage 6 • 410 bbls YF130ST Pad • 125 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 150 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF130ST w/4 ppa 16/20 Carbolite • 180 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 6 Stage 7 AK • • 450 bbls YF130ST Pad • 120 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF130ST w/4 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF130ST w/6 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Drop ball 7 Stage 8 • 450 bbls YF130ST Pad • 120 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF130ST w/2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF130ST w/4 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF130ST w/6 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Drop ball 8 Stage 9 • 450 bbls YF130ST Pad • 120 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF130ST w/4 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 6 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Drop ball 9 Stage 10 • 450 bbls YF130ST Pad • 120 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF130ST w/4 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF130ST w/6 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Drop ball 10 Stage 11 AK • • 450 bbls YF130ST Pad • 120 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF130ST w/4 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF130ST w/ 6 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Flush with 50 bbls of XL fluid (YF130ST) and 50 bbls linear fluid (WF130) and freeze protect • Total Sand: Approx. 1,498,615 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of 2E-01 and wells within 1/4 mile of 2E-01 2E-01: 7 5/8" Casing cement job was pumped on 9/9/2014 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by drilling mud, with full returns throughout job. The plug did not bump, but the floats held. Summary 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. It has also been determined that the frac will not adversely affect any nearby wells. Stimulation Surface Rig-Up AK • Co m Bleed/Tattle � Tale Tark 01011101:� IC`O ak * • Minimum pressure rating on all surface treating U lines 10,000 psi • Main treating line PRV is set to 95%of max [131110.1.4 OSI( treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and CO C set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. Co d a_ m Dal LF ��1►� @a a „tel dwed c� Pop-Off Tank PopOfFTank !�1 Pump Truck 0,N = Frac Pump -- Frac Pump Frac Pump Frac Pump Frac Pump - --j]-- - N- Frac Pump Stimulation Tree Saver AK . • • OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED /fR/1C IRON / CONNECTION i t . . ,.,,,Tf . ,„REMOTE OPERATED i .� MASTER VALVE 1•111111111""111111M ..i......<1.'H 1 411•11111111111111=1. 111111111111111110 1 MANUAL OPERATED it 0 MASTER VALVE errs Innimmin t:YI liZil /45 k Nrs le, 4111111M I t Stinger I ipo MANDREL I J lS „ -, VENT 1 • •••• -4--VALVE I I111 Illi/ 'lii MILS ;�: J �;,,•:®I '#I'■Vt. VENT/ALVE WELLHEAAND D ;01j,.....Ail VALVES ..- //%rirr. A OPEN WEUHEAv _ VALVES i.. i,•:-":„:, `. CLOSEDA �` -. 4r , Ai QUAD PACKOFF A 1I IIII rr, ASSEMBLY IN ••, •••,- ti. 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E N N N N N N N N I- W -O 0_ a_ c a. a_ 0_ -S O J CO 0 N E o o o O O O E CO CIS > U • • 4_ — O = -IS ° 73a; a) E -0 C6 0 0 C " co E w O o N • al -c_N_, ' O 73 CO CV NMLUM �ce' C6 cm O)- -0 (Z COc.o in N c.' >' c .N_ o E .& .� •V O '5 L U) c)- A , A , Cl) o cn4.- .o co � 0 A=. a) 0 =Q U t n/ oar � � � 0 = (a 0 H J _ = —0 —0 8 _ C 00 a) >1-- O -15 a) 9)) 0 1•c —0 o = �'03 10 s_ -0U -0 cn N 0 H m L .1..+ . . 0 0 0 2 22 = = as a-.) 0 ... — im L. c) v LL = a. O ccs " LL LL G> >+ a) si. — Q (" C -0 n O E O o N L_ co •cn -o O = •- -0 -0 — 1E O N O O 0 F— E $ N E E I . • 21001 (As-Drilled) Grass Roots Horizontal A-Sand Producer onocoPill�• ps Wellbore Schematic -1%jt - ro/22 J/7 'CAMERON 4-%'tree top oint is 4-/' 12.6:IBTM crossed over(for frac ecuipment) `-`�' f Last Edited- Existing Conductor: Callahan - 10/2012014 16" 62.6# H-40 - Drilpl ex j 9.0 -93ppg -110' MD/ 110'TVD 3'A'CamccCS r1 apple 2.375 4981.1D 13-1/2" Surface Hole Carnal 3-1,&'x 1" MttG1,1and.e!Q — 3,3101,10 Base West Sak:4,742'MD 13,171`TVD camcc 3-14-x1' 1 I Surface Casing t.11.1GMandrel 10-3/4" 45.5# L-80 Hydril 563 X044"r"D 4,939' MD!3,255' TVD @ 65° Carrico 3-;4'x 1' t.1 M G Mandrel A. 1 ©6613'MD LEND WBM Tubing: 9.5-10.0 PPG LI 3-V2"9.3#L-80 EU E8RD Camco 3-!,c x17 tnlGMandrel ea.'-J 9-718" Intermediate Hole ©Km.MD Estimated top of cement @+,. 10 912 MD Cameo 344 x t' J !MG Mandrel rZ "- 11,418 MD Intermediate Casing: Set in A5 7-5/8" 29.7# L-80 Hydril 563 Surface to 11.436'M D/ 5.950' TVD 7-5/8" 39#TN-110SS Hydril 563 Profile and SIdngS:'ee.e 11,428' MD! 5,949' TVD to 12,560' MD! forJetPump M6,161' TVD @ 85° Caanhole Press,re Gauge ' in3-1:"x 7-E:8'.PrevaerPacker 11,59°"I'D Top Kuparuk C: 12,132'MD/6,101'TVD Top Kuparuk t 5: 12,552'MD 6,160'TVD Flo-Pro WBM 4,,,„ 10.9 PPG i4h, I I I I :c.s 3%/Geo =h7: • • 2EH01 (As-Drilled)-SaConocoPhillips Grass Roots Horizontal A-Sand Producer Wellbore Schematic 'CAMERON 4-1/2"tree,top joint is 4-W 12.6#IBTM,crossed over(for frac equipment) • Last Edited: • Existing Conductor: Callahan-10/20/2014 16"62.6#H-40 9.OIpI9 3 ex -110'MD/110'TVD /: pp9 0 3 W Cameo DS Nipple 2.875" 498'MD 13-1/2"Surface Hole • Camco 3-'/,"x 1" MMG Mandrel @ 3,310'MD Base West Sak:4,742'MD/3,171'TVD Surface Casing Cameo 3-^/,"x 1" MMG Mandrel 10-3/4"45.5#L-80 Hydril 563 ©6,440'MD 4,939' MD/3,255'TVD 65° Cameo 3-K"x 1" \ MMG Mandrel W AV \� @8,618'MD LSND WBM Tubina: '' 9.5-10.0 PPG 3-'% 9.3#L-80 EUE8RD Cameo 3-14"x 1" MMG Mandrel 1 9-7/8"Intermediate Hole @10,200'MD ca, Estimated top• ca ent @+/-10,918'MD em la t�Camco andr l 1" MMG Mandrel @ Di i 41s'MD IntermedieCasing:Set inA57-5/8"29. L-80 Hydril 563Surface to1,436'MD/5,950'TVD 7-5/8"39# N-110SS Hydril 563Profile and Sliding Sleeve11;42 'MD/5949'TVD to 12,560' MD/ for Jet Pump 6;161'TVD @ 85° Downhole Pressure Gauge ': 3-%"x 7-5/8",Premier Packer 11,590'MD Top Kuparuk C:12,132'MD/6,101'ND Top Kuparuk A5: 12,552'MD 6,160'ND Flo-Pro WBM 10.9 PPG TCS 3 W Camco XN Nipple I I I I I I I I I 2.813"set at 74° • 7-5/8",ZXP Liner Top Packer 12,369' .. I II I I II I I I I 7-5/8"x 4-14"Baker Flex Lock ner hanger DEH w/RS Nipple, 12,391'MD.% TD:18,640 MD/6,266'ND Production Liner: 6-1/2"Production Hole 4-1/2" 12.6#L-80 Hydril 563 18,650' MD/6,266'TVD @ 88° • i Bettis, Patricia K (DOA) From: Klem,Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, October 22, 2014 9:38 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2E-01: Sundry Application Attachments: 2E-01 Well Schematic - Finaljpg Sorry, I must have typed the wrong info on the WBD...I thought I double checked it. Dang it, sorry.The TD is correct on form 10-403,TD was 18670'MD (6267'TVD) From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, October 22, 2014 9:27 AM To: Klem, Adam Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]KRU 2E-01: Sundry Application Good morning Adam, Would you please verify the total depth for KRU 2E-01. The permit to drill application stated the proposed depth of 18266' MD (6280'TVD); the wellbore schematic attached to the sundry application shows the total depth as 18640' MD (6266'TVD); whereas on the Form 10-403,total depth is stated as 18670' MD (6267'TVD). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, October 22, 2014 9:27 AM To: Adam.Klem@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: KRU 2E-01: Sundry Application Good morning Adam, Would you please verify the total depth for KRU 2E-01. The permit to drill application stated the proposed depth of 18266' MD (6280'TVD); the wellbore schematic attached to the sundry application shows the total depth as 18640' MD (6266'TVD); whereas on the Form 10-403, total depth is stated as 18670' MD (6267'TVD). 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 RECEIVED • STATE OF ALASKA • OCT 21 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND11.4a@C la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., ✓•.b•t6 12.Permit to Drill Number: 2 t' ConocoPhillips Alaska, Inc. orAband.: September 2e,2014' 214-076/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 August 26,2014 • 50-029-23516-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: w•st•t4 Surface: 4775'FNL,5120'FEL,Sec.36,T11N, RO9E, UM September 17,2014 • �C..'�1.3 2E-01 a'rss Top of Productive Horizon: 8. KB(ft above MSL): 132'RKB 15.Field/Pool(s): 897'FNL, 1852'FEL,Sec. 10,T1ON, RO9E, UM GL(ft above MSL): 105'AMSL Kuparuk River Field - Total Depth: 1731'FNL,2096'FEL,Sec. 15,T1ON, RO9E, UM 9.Plug Back Depth(MD+ND): 18670'MD/6267'TVD Kuparuk River Oil Pool . 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-529972 y- 5944147 Zone-4 18670'MD/6267'TVD . ADL 25658,25665,25666,392364 ` TPI: x-522712 y- 5937441 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-522497 y- 5931327 Zone-4 nipple @ 498'MD/498'TVD 2584,2586,2178 18.Directional Survey: Yes Q• No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1519'MD/1488'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron Density not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND 1 HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 28' 107' 28' 107' 24" Coldset II 10.75" 45.5# L-80 27' 4940' 27' 3255' 13.5" 1816 sx Class G, 197 sx Class G 7.625" 29.7# L-80 26' 11430' 26' 5947' 9.875" 446 sx Class G 7.625" 39# TN-110 11430' 12560' 5947' 6161' 9.875" same as above 4.5" 12.6# L-80 12369' 18650' 6141' 6266' 6.5" frac sleeve 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 12393' 11493'MD/5963'TVD, not perforated 12369'MD/6141'TVD f 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ■ JL. /� Was hydraulic fracturing used during completion? Yes No❑ mij......I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) / waiting on facility hook-up V Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(torr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012v.,7/..._ cri)714)- ._, C.ONTINUED ON REVER E _ Submit original only ' g //.� RBDM JAN - 6 203 G 29. GEOLOGIC MARKERS(List all formations and mar•ncountered): 30. • FORMATION TESTS NAME MD TVD Well tested? Yes O No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1519' 1488' needed,and submit detailed test information per 20 AAC 25.071. Top Ugnu(Ugnu C) 2149' 2026' Top W Sak 3488' 2674' Base W Sak 4742' 3171' Top HRZ 10732' 5676' Upper Kalubik 11277' 5900' Lower Kalubik 11637' 5994' Kuparuk C 12130' 6100' Kuparuk B1 12140' 6102' Kuparuk A6 12383' 6145' Kuparuk A5 12546' 6159' N/A Formation at total depth: Kuparuk A5 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,cement detail sheets 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan @ 263-4180 Pee- Email: Mike.Callahan(a�conocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature 4 Phone 265-6120 Date `,21Z r 44 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. 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 4b: TPI(Top of Producing Interval). Item 8: 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump,Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP PROD 2E-01 • `IP f C0110CQ�1����n 5 4 Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore API/U WI Field Name Wellbore Status Inc!I°) MD(ftKB) Act Btm(ftKB) CLMr.r'3h,ig,m j 500292351600 KUPARUK RIVER UNIT PROD 91.99 13,006.40 18670.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 1 Rig Release Date° 2E-01.10/17/20141.27:41 PM SSSV:NIPPLE Last WO: 27.501 9/23/2014 Vertical schematic(actual) - _- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 241- Last Tag: Rev Reason:NEW WELL,GLV C/O,PULLED haggea 10/13/2014 ..... ..................................._. -4<..,i - '°� ����������� CATCHER,BALL/ROD,RHC • Strings ::. C ng Description OD(in) ID(m) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 27.6 106.6 106.6 62.50 H-40 Welded Casing Description OD(in) ID(m) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...'Grade Top Thread X0 Enlarging;fi5.2 �, SURFACE 10 3/4 9.950 26.9 4,939.0 3,254.8 45.50 L-80 HYD 563 / "AACONDUCTOR;27.6106.60. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread MI, INTERMEDIATE 75/8 6.875 26.0 12,560.3 6,1608 29.70 L-80 Hyd 563 NIPPLE;497.5 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,368.6 18,650.0 6,266.3 12.60 L-80 Hyd563 GAS LIFT;3,309.7 �I Liner Details I 3 Top(ftKB) To D ftKB To Incl Item Des Com Nominal ID P(TVD) 1 P fl (inl SURFACE;26.94,939.0 + 12,368.6 6,140.5 83.97 PACKER HRD ZXP LINE TOP PACKER 5.750 GAS LIFT;6,440.3 - 12,388.2 6,142.6 84.07 NIPPLE RS PACKOFF SEAL NIPPLE 4.270 1111 12,390.6 6,142.8 84.08 HANGER FLEX LOCK LINER HANGER 4.800 GAS LIFT;8,617.8 III 12,574.6 6,162.4 83.75 SWELL TAM SWELL PACKERr(14) 3.958 1111 PACKER GAS LIFT;10,199.9 INK 12,723.7 6,172.4 89.57 FRAC PORT BAKER FRAC SLEEVE 2.125 1 12,823.7 6,171.9 90.95 SWELL TAM SWELL PACKER(13) 3.958 as GAS LIFT;11,416.0 ae. PACKER I 13,009.9 6,166.9 91.97 SWELL TAM SWELL PACKER(12) 3.958 SLIDING SLV;11,M3.2 IPACKER 13,324.7 6,159.5 90.59 FRAC PORT BAKER FRAC SLEEVE(9)2.01"seat for 2.063"ball 2.063 GAUGE;11.467.9 - PACKER;11.492.713,675.4 6,167.7 8727 SWELL TAM SWELL PACKER(11) 3.958 PACKER NIPPLE;11,520.9 13,776.9 6,172.9 87.10 SWELL TAM SWELL PACKERr(10) 3.958 PACKER LOCATOR;12,361.4 �I 14,008.4 6,181.2 87.98 FRAC PORT BAKER FRAC SLEEVE(8)1.948"seat for 2"ball 2.000 MULE SHOE;12,391.9 'i P:. 14,275.8 6,188.7 88.49 SWELL TAM SWELL LPACKER(9) 1958 PACKER 14,506.7 6,194.4 88.31 FRAC PORT BAKER FRAC SLEEVE(7)seat for 1.938"ball 1.938 14,731.7 6,199.7 88.52 SWELL TAM SWELL PACKER(8) 3.958 INTERMEDIATE;25.9-12,560.3 PACKER - - 14,964.4 6,204.5 88.89 FRAC PORT BAKER FRAC SLEEVE(6)seat for 1.875"ball 1.875 15,231.4 6,215.2 87.26 SWELL TAM SWELL PACKER(7) 3.958 PERFP;12,723.612,725.9 a PACKER 15,375.4 6,220.5 88.57 SWELL TAM SWELL PACKER(6) 1958 PACKER ■ 15,649.7 6,218.0 90.10 FRAC PORT BAKER FRAC SLEEVE(5)seat for 1.813"bag 1.813 15,959.4 6,217.8 89.97 SWELL TAM SWELL PACKER(5) 3.958 PACKER PERFP;13,324.7-13,327.0 16,276.7 6,227.0 87.32 FRAC PORT BAKER FRAC SLEEVE(4)seat for 1.688"ball 1.688 16,544.0 6,235.8 88.94 SWELL TAM SWELL PACKER(4) 3.958 ■ PACKER 16,860.1 6,237.5 8924 FRAC PORT BAKER FRAC SLEEVE(3)seat for 1.625"ball 1.625 17,167.8 6244.9 89.14 SWELL Tam Swell Packer(3) 3.958 PERFP;14,008.4-14.010.7 S PACKER 17,439.1 6,250.4 88.36 FRAC PORT Baker Frac sleeve(2)1.51"seat for 1.563"bat 1.563 17,746.9 6257.4 89.04 SWELL PACKER Tam Swell Packer(2) 3.958 Z PERFP;14,506.7-14,503.0 18,021.6 6261.6 89.62 FRAC PORT Baker Frac sleeve(1)1.448"Seat for 1.50"ball 1.500 18,330.9 6,261.2 90.57 SWELL Tam Swell Packer(1) 3.958 PACKER PERFP;14,064.4-14,566.7 18,523.9 6,261.9 88.43 SLEEVE(DEH) PACKERS PLUS DEH,BTC 3.750 18,597.6 6,264.3 87.84 SLEEVE(TCS) PACKERS PLUS TCS,4-1/2"ETC 1.000 • Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection PERFP;15,649.615,651.9 ; TUBING 4 1/2 x 3 1/2 3 1/2 2992 24.1 12,393.0 6,143.1 9.30 L-80 EUE 8/d @ 65.2 . Completion Details Z Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) PERFP;16,276.7-16,279.0 24.1 24.7 0.00 HANGER CIW TUBING HANGER 3.910 65.2 65.2 0.08 XO Enlarging XO,2',4-7/2'12.68 L-80 IBTM box x 3-1/2"9.311 L-80 2.937 EUE 8RD-Mod pin PERFP;16,860.1-16,862.4 1.---s 497.5 497.4 2.34 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 11,443.2 5,950.6. 74.32 SLIDING SLV BAKER CMU SLIDING SLEEVE w/DS nipple w/2.813" 2.810 profile 11,467.9 5,957.1 75.03 GAUGE SCHLUMBERGER GAUGE CARRIER 2.992 PERFP;17,439.1-17,441.3 11,492.7 5,963.4 75.73 PACKER BAKER PREMIER PRODUCTION PACKER 2.930 11,520.9' 5,970.1 76.53 NIPPLE CAMCO"D"NIPPLE 2.750 12,361.4 6,139.8 83.77 LOCATOR SHEAR PINNED FLUTED NO-GO SUB 3.000 12,391.9 6,143.0 84.08 MULE SHOE MULE SHOE WLEG 2.980 sil Perforations&Slots II Shot Dens Top(ND) atm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,723.7 12,725.9 6,172.4 6,172.4 9/20/2014 PERFP FRAC PORT 13,324.7 13,327.0 6,159.5 6,159.4 9/20/2014 PERFP FRAC PORT 14,008.4 14,010.7 6,181.2 6,181.3 9/20/2014 PERFP FRAC PORT LINER;12,368.618,650.0 KUP PROD • 2E-01 ConocoPhillips - Alaska,Inc, `,;` ;` ((...Y,atawp. -•- 2E-01,10/1720141:2743 PM Vertical Schematic(actual) HANGER;24.1 1_;: Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shutoff X0 Enlarging 65.2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 14,506.7 14,509.0 6,194.4 6,194.4 9/20/2014PERFP FRAC PORT .A.AJ CONDUCTOR;27 6-106 649. M 14,964.4 14,966.7 6,204.5 6,204.6 9/20/2014 PERFP FRAC PORT NIPPLE;497.5 - Iii.ii 15,649,7 15,651.9 6,218.0 6,218.0 9/20/2014 PERFP FRAC PORT GAS LIFT;3,309.7 II 16,276.7 16,279.0 6,227.0 6,227.1 9/20/2014 PERFP FRAC PORT gnu 16,860.1 16,862.4 6,237.5 6,237.6 9/20/2014 PERFP FRAC PORT F 1 17,439.1 17,441.3 6,250.4 6,250.4 9/20/2014 PERFP FRAC PORT SURFACE,26.9-0,939.0 GAS LIFT;s,4ao3 ' IM Mandrel Inserts MIS St MIS oil GAS LIFT,8,617.6 Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com AIM —I' GAS LIFT,10,199.9 3,309.7 2,604.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 2 6,440.3 3,878.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 III 3 8,617.9 4,805.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/6/2014 DCK-2 GAS LIFT,11,416.0 tat I'1 4 10,199.9 5,459.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 SLIDING sLv;11,443.2 � 5 11,416.0 5,943.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/22/2014 Notes:General&Safety GAUGE;11,4679 -- End Date Annotation PACKER;11,492.7 NOTE: Mr NIPPLE,11,520.9 IMF LOCATOR,12,361.4 d MULE SHOE;12,391.9 ' I I INTERMEDIATE;25.9-12,560.3 PERFP,12,723.6-12.7259 I U- . PERFP;13,3247-13,327.0 I U PERFP,14008.4-14,010.7 PERFP;14506.7-14,509.0 — PERFP,14,964.4-14966.7 S U- . PERFP;15,649.6-15,651.9 2 PERFP;16,276.7-16,279.0 PERFP,16,660.1-16.862 4 PERFP,17,439.1-17,441.3 _- . I LINER;12,368.6-18,650.0 • • Cement Detail Report ke2E-01 CanocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,8/24/2014 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/9/2014 00:30 9/9/2014 03:45 2E-01 Comment Pump 35 bbls CW 100 @ 4.9 bpm,570 psi.,followed by 40 bbls of Mud Push II @ 3 bpm,417 psi.. Drop bottom plug. Pump 76 bbls 15.8 ppg Class G cmt.@ 2 to 4.5 bpm 200 to 500 psi. Pump unit having problems delivering cmt.from silo to mix tub.Stop and batch mix cmt.Continue pumping 15.8 ppg Class G cmt to 84 bbls total pumped.2bpm 220 psi.Stop to batch mix remaining cement. Pump remaining cmt.for a total of 94 bbls. Drop top plug. Pump 10 bbls water. Displace cement with rig pumps. Pump total of 560.9 bbls.6 bpm for 550 bbls.Slow pump to 3 bpm final 5 bbls. Reciprocate entire job with full returns. Did not bump plug.Final pressure @ 3 bpm=600 psi. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 10,918.0 12,570.0 Yes Yes Yes Cement Q Pump!nit(bbllm...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 6 6 500.0 0.0 No 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 35 bbls CW 100 @ 4.9 bpm,570 psi.,followed by 40 bbls of Mud Push II @ 3 bpm,417 psi.. Drop bottom plug. Pump 76 bbls 15.8 ppg Class G cmt.@ 2 to 4.5 bpm 200 to 500 psi. Pump unit having problems delivering cmt.from silo to mix tub.Stop and batch mix cmt.Continue pumping 15.8 ppg Class G cmt to 84 bbls total pumped.2bpm 220 psi.Stop to batch mix remaining cement. Pump remaining cmt.for a total of 94 bbls. Drop top plug. Pump 10 bbls water. Displace cement with rig pumps. Pump total of 560.9 bbls.6 bpm for 550 bbls. Slow pump to 3 bpm final 5 bbls. Reciprocate entire job with full returns. Did not bump plug.Final pressure @ 3 bpm=600 psi. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush CW 100 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush Mud Push II 40.0 Yield(ft'/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 446 G 92.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 113.0 4.00 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Page 1/1 Report Printed: 10/16/2014 • •' d }� 4;hST Cement Detail Report 2E-01 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/24/2014 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/30/2014 22.30 8/31/2014 02:30 2E-01 Comment SLB pump 75 bbls 10.5 ppg mud push&drop bottom plug. Pump 618 bbls 11 ppg lead,followed by 61.7 bbls 12 ppg tail cement. Drop top plug, SLB pumped 10 bbls H2O, Displace with rig pump @ 5.5 bpm,400 psi.Slow pump to 3 bpm to bump plug. FCP 850 psi, pressure up to 1400 psi,hold for 5 mins. bled pressure off,check the floats.good.CIP @ 02:30 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 28.0 4,950.0 No 128.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 850.0 1,400.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment SLB pump 75 bbls 10.5 ppg mud push&drop bottom plug. Pump 618 bbls 11 ppg lead,followed by 61.7 bbls 12 ppg tail cement. Drop top plug, SLB pumped 10 bbls H2O, Displace with rig pump @ 5.5 bpm,400 psi.Slow pump to 3 bpm to bump plug. FCP 850 psi, pressure up to 1400 psi, hold for 5 mins. bled pressure off,check the floats.good.CIP @ 02:30 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push 75.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.0 4,374.0 1,816 G 613.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 79.5 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 4,374.0 4,950.0 197 G 63.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.62 5.38 12.00 128.5 0.00 1,000.0 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 lbs/bbl Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Page 1/1 Report Printed: 10/16/2014 • • ConocoPhiIIips Time Log & Summary Wepview Web Reporting Report Well Name: 2E-01 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 8/25/2014 3:30:00 PM Rig Release: 9/23/2014 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/24/2014 24 hr Summary Finish prepping for rig move. Move rig from 2E-02 to 2E-01. Complete rig acceptance checklist. Rig accepted @ 15:30 hrs. Nipple up diverter system.Take mud into pits. Change over handling equipment to 5". Service rig&perform pre-spud derrick inspection. PU 5"DP. Perform diverter drill,with AAR afterwards. 06:00 07:00 1.00 0 0 MIRU MOVE RURD P Prep for rig move. 07:00 08:00 1.00 0 0 MIRU MOVE MOB P PJSM w/Peak drivers. Move rockwasher, boiler, motor, pump, pits, &pipe shed modules to stage area. 08:00 08:30 0.50 0 0 MIRU MOVE PRLO P Prep pad to move sub base. 08:30 08:45 0.25 0 0 MIRU MOVE MOB P Move sub base off of 2E-02. 08:45 10:00 1.25 0 0 MIRU MOVE PRLO P Prep pad to crab over to 2E-01 10:00 10:30 0.50 0 0 MIRU MOVE MOB P Spot sub base over 2E-01 10:30 11:00 0.50 0 0 MIRU MOVE PRLO P Lay mats for rig modules. 11:00 13:45 2.75 0 0 MIRU MOVE MOB P Spot pits, pump, motor, boiler, pipe &rockwasher modules. 13:45 15:30 1.75 0 0 MIRU MOVE RURD P Work on rig acceptance checklist hooking up interconnect lines& cables. Rig accepted @ 15:30 hrs. 15:30 17:00 1.50 0 0 MIRU MOVE NUND P Nipple up diverter system, install hydraulic lines, &riser. 17:00 18:00 1.00 0 0 MIRU MOVE RURD P Pick up tools from beaver slide.Take on mud to the pits. 18:00 19:45 1.75 0 0 MIRU MOVE RURD P C/O TD handling egipment from 4" XT39 to 4 1/2" IF. 19:45 20:30 0.75 0 0 MIRU MOVE RURD P C/O rig floor handling equipment to 5". 20:30 21:00 0.50 0 0 MIRU MOVE SVRG P Service Rig. 21:00 22:00 1.00 0 0 MIRU MOVE SVRG P Pre-spud derrick inspection. 22:00 23:30 1.50 0 0 MIRU MOVE PULD P Pick up 5" DP and stand back in derrick. 23:30 23:45 0.25 0 0 MIRU MOVE SFTY P Held diverter drill with muster to safe breifing area. Performed MR. CRT= 225 seconds 23:45 00:00 0.25 0 0 MIRU MOVE PULD P Pick up 5"DP and stand back in derrick. 08/25/2014 Finish picking up 5"DP&standing back in derrick. Mobilize BHA to shed&floor. Perform diverter drill,with AAR afterwards. Pre-spud meeting with entire rig team. Level sub base. Perform diverter test,witnessed by AOGCC Jeff Jones. Change out cable on skate. Pick up clean out BHA. Fluid check all lines&stack. Clean out conductor to 130' MD. L/D BHA 1 &P/U BHA 2. Shallow test with ARC logging tool not responding. Plug in&reboot, good. Shallow test LWD, MWD, &gyro,good. Page 1 of 29 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 MIRU MOVE RURD P Load BHA in pipe shed and stage on short side. 01:00 04:00 3.00 0 0 MIRU MOVE PULD P Pick up 5"DP, HWDP&jars. Sim-ops take on spud mud to pits. 04:00 04:30 0.50 0 0 MIRU MOVE SFTY P Held diverter drill with muster to safe briefing area. Performed AAR. CRT= 285 seconds. 04:30 05:30 1.00 0 0 MIRU MOVE RURD P Move BHA tools up the beaver slide to the rig floor. 05:30 06:30 1.00 0 0 MIRU MOVE SEQP P Function test diverter system 06:30 07:00 0.50 0 0 MIRU MOVE SVRG P Finish pre-spud derrick inspection. 07:00 07:30 0.50 0 0 MIRU MOVE SFTY P Pre-spud meeting with crew&3rd parties. 07:30 08:45 1.25 0 0 MIRU MOVE PSIT P Level sub base. 08:45 10:15 1.50 0 0 MIRU MOVE BOPE P Function test diverter, 12 sec for knife valve to open&30 sec for annular to close. Test gas alarms, test pit level alarms&accumulator draw down test. Initial system psi 2900 psi; psi after closure 1800 psi; time to attain 200 psi 40 sec;full psi attained in 188 sec. 5 back up bottles of nitrogen averaged 1975 psi. Test witnessed by AOGCC Rep.Jeff Jones. 10:15 10:30 0.25 0 0 MIRU MOVE SFTY T PJSM for changing out skate cable. 10:30 14:00 3.50 0 0 MIRU MOVE RGRP T Change out skate cable. 14:00 15:45 1.75 0 0 MIRU MOVE PULD P Pick up clean out BHA as per SLB DD. 15:45 16:00 0.25 0 32 MIRU MOVE CIRC P TIH to 32' MD. Circulate mud throughout system&PT lines to 3000 psi. 16:00 18:00 2.00 32 130 SURFA( DRILL DRLG P Clean out conductor from 32'-130' MD, 450 gpm, 300 psi, 50 rpm, Tq 1.5k,WOB 4-5k. 18:00 18:15 0.25 130 38 SURFA( DRILL TRIP P TOH from 130-38'MD, rack back HWDP. 18:15 21:45 3.50 38 130 SURFA( DRILL PULD P Make up BHA as per SLB DD. 21:45 22:30 0.75 130 130 SURFA( DRILL CIRC T Shallow hole test tools,with ARC unresponsive.450 gpm,400 psi. Troubleshoot GWD. 22:30 23:00 0.50 130 114 SURFA( DRILL EQRP T Plug into SLB ARC logging tool. Reboot and test good. 23:00 00:00 1.00 114 130 SURFA( DRILL CIRC P Shallow hole test ARC, MWD, & Gyro&450 gpm, 450 psi. X8/26/2014 Drilled as per plan from 125'-1710'MD, 1660'TVD. Discontinued using gyro tool @ 912' MD/908'TVD,to use SLB MWD for survey data. 00:00 02:00 2.00 130 215 SURFA( DRILL DDRL P Drill from 130'-215' MD, 215'TVD, PU 49K, SO 52K, ROT 49K,Tq on 1.5K, off 0, ECD 10.0 ppg, FO 80%,WOB 5-7K, RPM 60, GPM 475,450 PSI. Page 2 of 29 • Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:15 0.25 215 125 SURFA( DRILL TRIP P TOH from 215'-125' MD, racking back one stand of HWDP. Shoot gyro check shot at 215'MD. 02:15 03:00 0.75 125 215 SURFA( DRILL PULD P Single in the hole w/3 NMFC. 03:00 06:00 3.00 215 348 SURFA( DRILL DDRL P Drill from 215'-348' MD, 348'TVD, ADT 3.69,AST.46, JARS 134.69, BIT 3.69, PU 63K, SO 65K, ROT 65K, Tq on 1.5K, off 1, ECD 10.6 ppg, FO 80%,WOB 15-20K, RPM 60, GPM 470, 590 PSI. 06:00 12:00 6.00 348 790 SURFA( DRILL DDRL P Drill from 348'-790' MD, 788'TVD, ADT 3.83,AST 1.95, JARS 138.52, BIT 7.52, PU 72K, SO 74K, ROT 76K, Tq on 4-5K, off 1, ECD 10.08 ppg, FO 75%,WOB 20-25K, RPM 60, GPM 470, 720 PSI. Spill Drill CRT= 159 sec @ 10:30 hrs. 12:00 18:00 6.00 790 1,270 SURFA( DRILL DDRL P Drill from 790'-1281'MD, 1270'TVD, ADT 3.78,AST 1.65, JARS 142.3, BIT 11.3, PU 87K, SO 86K, ROT 87K, TQ ON 4-8K, OFF 1, ECD 9.87 ppg, FO 74%,WOB 23-27K, RPM 60, GPM 550, 975 PSI. 18:00 00:00 6.00 1,270 1,710 SURFA( DRILL DDRL P Drill from 1281'-1710'MD, 1660'TVD, ADT 4.29,AST 1.84,JARS 145, BIT 14.17, PU 99K, SO 89K, ROT 93K, TQ ON 3-5K, OFF 1, ECD 9.99 ppg, FO 74%, WOB 5-10K, RPM 60, GPM 550, 950 PSI. Kick w/drilling CRT=62 sec @ 23:30 hrs 38/27/2014 Drilled as per plan from 1710'-3549'MD, 2690'TVD. Pumped sweeps&mud dilutions as needed. Continued to drift, strap, &tally 10.75"casing in the pipe shed. 00:00 06:00 6.00 1,710 2,161 SURFA( DRILL DDRL P Drill from 1710'-2161'MD, 2043'TVD, ADT 2.76,AST 2.07,JARS 147.93, BIT 16.93, PU 105K, SO 86K, ROT 92K, TQ ON 5-7K, OFF 2-7K, ECD 9.9 ppg, FO 72%,WOB 2-5K, RPM 60, GPM 540, 1000 PSI. Fire Drill CRT= 120 sec @ 05:00 hrs. 06:00 12:00 6.00 2,161 2,610 SURFA( DRILL DDRL P Drill from 2161'-2610' MD, 2315'TVD, ADT 3.39, AST 2.65,JARS 151.32, BIT 20.32, PU 103K, SO 90K, ROT 92K,TO ON 3-4K, OFF 3-4K, ECD 9.78 ppg, FO 78%,WOB 20-30K, RPM 80, GPM 648, 1330 PSI. 12:00 18:00 6.00 2,610 3,121 SURFA( DRILL DDRL P Drill from 2610'-3121' MD, 2530'TVD, ADT 3.57,AST 1.88, JARS 154.89, BIT 23.89, PU 106K, SO 83K, ROT 92K, TQ ON 6-8K, OFF 4-6K, ECD 10.01 ppg, FO 77%,WOB 20-25K, RPM 80, GPM 650, 1625 PSI. Page 3 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,121 3,549 SURFA( DRILL DDRL P Drill from 3121'-3549'MD, 2690'TVD, ADT 4.09,AST.23, JARS 158.98, BIT 27.98, PU 107K, SO 84K, ROT 96K, TQ ON 4-12K, OFF 4-6K, ECD 9.99 ppg, FO 77%,WOB 10-15K, RPM 80, GPM 650, 1550 PSI. _ Spill Drill CRT=77 sec @ 20:00 hrs. 08/28/2014 Drilled as per plan to TD,from 3459'-4950'MD, 3259'TVD. Pumped sweeps&mud dilutions as needed. CBU 2X to condition mud. Monitor well,static. BROOH from 4950'-4205'MD. 00:00 06:00 6.00 3,549 3,921 SURFA( DRILL DDRL P Drill from 3549'-3921'MD, 2853'TVD, ADT 3.71,AST 1.56,JARS 162.69, BIT 31.69, PU 110K, SO 89K, ROT 97K, TQ ON 5-9K, OFF 4-8K, ECD 10.05 ppg, FO 76%,WOB 20-35K, RPM 60-80, GPM 671, 1600 PSI. 06:00 12:00 6.00 3,921 4,383 SURFA( DRILL DDRL P Drill from 3921'-4383'MD, 3028'ND, ADT 3.65,AST.2,JARS 166.34, BIT 35.34, PU 115K, SO 90K, ROT 100K,TQ ON 7-10K, OFF 4-5K, ECD 10.34 ppg, FO 78%,WOB 25-30K, RPM 80, GPM 707, 1950 PSI. 12:00 18:00 6.00 4,383 4,846 SURFA( DRILL DDRL P Drill from 4383'-4846'MD, 3214'ND, ADT 4.60,AST.4,JARS 170.94, BIT 39.94, PU 114K, SO 94K, ROT 104K,TQ ON 8-12K, OFF 6-8K, ECD 10.29 ppg, FO 79%,WOB 15-20K, RPM 80, GPM 750, 2175 PSI. 18:00 20:00 2.00 4,846 4,950 SURFA( DRILL DDRL P Drill from 4846-4950'MD, 3259'ND, ADT 1.4,AST 0, JARS 172.34, BIT 41.34, PU 114K, SO 94K, ROT 107K,TQ ON 8-12K, OFF 6-8K, ECD 10.34 ppg, FO 87%,WOB 20-24K, RPM 80, GPM 750,2350 PSI. 20:00 22:15 2.25 4,950 4,950 SURFA( CASING CIRC P CBU 2X to condition the mud to a 9.6 ppg,675 gpm,2100 psi, 80 rpm, Tq 6-8K 22:15 22:45 0.50 4,950 4,950 SURFA( CASING OWFF P Monitor well,static. 22:45 00:00 1.25 4,950 4,205 SURFA( CASING REAM P BROOH from 4950'-4205'MD,675 GPM, 1800 PSI,TQ 6-8K, PU 98K, SO 96K, ROT 102K, FO 78% 08/29/2014 BROOH out of 13.5"surface hole&laid down BHA 2. Rigged up Volant CRT&RIH with 10.75"surface casing to 1800' MD. 00:00 01:00 1.00 4,205 3,923 SURFA( CASING REAM P BROOH from 4205'-3923'MD,675 gpm, 1800 psi, FO 87%, 80 rpm, PU 98K, SO 95K, ROT 102K 01:00 01:30 0.50 3,923 3,923 SURFA( CASING CIRC P Circulate&condition mud with shakers unloading. Circ @ 469 gpm, 950 psi, FO 77%, 80 rpm,Tq 6K Fire Drill CRT= 154 sec @ 01:00 hrs. Page4of29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 07:45 6.25 3,923 1,609 SURFA( CASING REAM P BROOH from 3923'-1609' MD, 675 gpm, 1500 psi, 80 rpm, Tq 5-6K, 750 fph. High torque @ 1830'-1794'& 1702', ream 2X, orient high side and slide through no problem. 07:45 11:00 3.25 1,609 776 SURFA( CASING REAM P BROOH from 1609'-776' MD,600 gpm, 1140 psi, 80 rpm, Tq 2-3K,. 1270'-1150'@ 200 fph; 1150'-961'@ 750 fph;961'-776'@ 200 fph. 11:00 12:00 1.00 776 221 SURFA( CASING TRIP P Pump out of hole from 776'-221'MD, 400gpm,350 psi,600 fph. 12:00 14:30 2.50 221 0 SURFA( CASING PULD P Lay down BHA 2 as per SLB DD. Calculated fill for trip 23.4, actual 36.5 bbls. 14:30 15:00 0.50 0 0 SURFA( CASING RURD P Clear&clean rig floor. 15:00 17:45 2.75 0 0 SURFA( CASING RURD P Pick up tools and rig up to run casing. 17:45 22:30 4.75 0 1,633 SURFA( CASING RNCS P PJSM, Run 10.75",45.5#, L-80, Hydril 563 casing. Baker-loc shoe track¢ralize as per detail. RIH to 1633' MD. 22:30 23:30 1.00 1,633 1,633 SURFA( CASING CIRC P Circulate casing volume,staging up the pumps 1.5-4 bpm, 150 psi, PU 91 K, SO 84K. 23:30 00:00 0.50 1,633 1,800 SURFA( CASING RNCS P RIH from 1633'-1800'MD, PU 95K, SO 87K 08/30/2014 Finished RIH with 10.75"surface casing to 4939' MD,washing down 4280'-4895'MD. Make up hanger& landing joint. Circulate&condition mud for cement job. Cement as per plan with 420 bbls of lead cement pumped away at 24:00 hrs. 00:00 01:00 1.00 1,800 2,025 SURFA( CASING RNCS P RIH from 1800'-2025' MD,Work over ledge @ 1935'MD,2 bpm, 200 psi, 15 rpm, Tq 8-10K, PU 110K, SO 90K. 01:00 01:45 0.75 2,025 2,025 SURFA( CASING CIRC P CBU, staging up to 4 bpm, 150 psi, 100%increase in cuttings @ BU. 01:45 04:00 2.25 2,025 2,817 SURFA( CASING RNCS P RIH from 2025'-2817'MD, PU 140K, SO 95K 04:00 05:00 1.00 2,817 2,817 SURFA( CASING CIRC P CBU staging up to 4 bpm,200 psi, PU 144K, SO 145K. 05:00 07:30 2.50 2,817 3,643 SURFA( CASING RNCS P RIH from 2817'-3643'MD, PU 150K, SO 95K 07:30 10:00 2.50 3,643 3,643 SURFA( CASING CIRC P Circulate&condition to reduce MW to 9.6ppg,stage up to 5 bpm, 225 psi. 10:00 11:15 1.25 3,643 4,280 SURFA( CASING RNCS P RIH from 3643'-4280'MD, PU 170K, SO 99K. 11:15 15:00 3.75 4,280 4,895 SURFA( CASING RNCS P RIH from 4280'-4895'MD, pumping each joint down,4 bpm, 325 psi. 15:00 15:15 0.25 4,895 4,939 SURFA( CASING HOSO P PU hanger&make up w/Volant CRT, make up landing joint&land hanger @ 4939'MD, PU 210K, SO 110K. 15:15 20:45 5.50 4,939 4,939 SURFA( CEMEN-CIRC P Circulate&condition mud for cement, reciprocate string,stage up pumps 4-7.5 bpm,250 psi. Page5of29 1 Time Logs • Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 20:45 21:15 0.50 4,939 4,939 SURFA( CEMEN-RURD P Rig down Volant CRT, RU cement head. 21:15 21:45 0.50 4,939 4,939 SURFA( CEMEN-SFTY P PJSM for cementing 10.75"surface casing. Circulate&recipicate @ 7.5 bpm,425 psi, PU 215K, SO 115K. 21:45 22:30 0.75 4,939 4,939 SURFA( CEMEN-SEQP P Prime up cement unit, pump 5bbl H2O, PT lines to 3000 psi for 5 min, test good. 22:30 00:00 1.50 4,939 4,939 SURFA( CEMEN-CMNT P SLB pump 75 bbls 10.5 ppg mud push, drop bottom plug, batch up 11 ppg lead cement, pump 420 bbls lead cement @ 6.5 bpm, 200 psi, recipicating string PU 235K, SO 120K, 08/31/2014 Cemented as per plan,with CIP @ 02:30 hrs.Wash up surface equipment. Nippled down diverter system& nippled up well head with BOPE.Tested BOPE w/5"test joint to 3500 psi. 00:00 03:00 3.00 4,939 4,939 SURFA( CEMEN-CMNT P PJSM. Continue surface cement job. Pump 618 bbls 11 ppg lead,followed by 61.7 bbls 12 ppg tail cement. Drop top plug, SLB pumped 10 bbls H2O, Displace with rig pump @ 5.5 bpm,400 psi. Slow pump to 3 bpm to bump plug. FCP 850 psi, pressure up to 1400 psi, hold for 5 mins. bled pressure off, check the floats. good. CIP @ 02:30 hrs. 03:00 06:00 3.00 4,939 0 SURFA( CEMEN-RURD P Flush stack, flow line, landing joint, drain stack. Clear and clean rig floor. Lay down all cementing and casing running tools. 06:00 09:30 3.50 0 0 SURFA( CEMEN-NUND P Nipple down riser&surface diverter system. Dress wellhead. 09:30 10:30 1.00 0 0 SURFA(WHDBO NUND P Nipple up wellhead, 10:30 11:00 0.50 0 0 SURFA(WHDBO PRTS T Attempt to test hanger to wellhead to 5000 psi, no test. 11:00 12:00 1.00 0 0 SURFA(WHDBO NUND T Nipple down wellhead. 12:00 14:15 2.25 0 0 SURFA( WHDBO NUND T Finish N/D wellhead. Change out seals. N/U wellhead. 14:15 14:30 0.25 0 0 SURFA( WHDBO PRTS P PT seals between wellhead&casing hanger to 5000 psi for 10 min. CPAI Drilling Supervisor witnessed. 14:30 16:15 1.75 0 0 SURFA( WHDBO NUND P Nipple up BOPE. 16:15 17:00 0.75 0 0 SURFA(WHDBO RURD P Rig up testing equipment for BOPE test. _ 17:00 18:15 1.25 0 0 SURFA(WHDBO EQRP T Attempt first test with wellhead gland nuts, test ports, &valve grease port leaking.Tightened gland nuts and test ports. 18:15 20:00 1.75 0 0 SURFA(WHDBO BOPE P Test BOPE w/5"jt,to 250/3500 psi, for 5 min each,charted.#1 Top VBR's; CV's 1,12,13,14; Manual kill valve.#2 Upper IBOP; HCR kill; CV's 9,11.#3 Lower IBOP; CV's 5,8,10. #4 Dart valve; CV's 4,6,7. Page 6 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:15 1.25 0 0 SURFA( WHDBO EQRP T Shut down to have Cameron representatives inspect wellhead. 21:15 00:00 2.75 0 0 SURFA( WHDBO BOPE P Continue BOPE test.#5 FSV; CV 2. #6 HCR choke, kill line Demco valve. #7 Man. choke, HCR kill.#8 Annular #9 Lower VBR's#10 Blind rams, CV 3.Test manual&hydraulic chokes. Accumulator test: Initial system psi =3000 psi; Pressure after closure 1800 psi;200 psi attained 45 seconds; Full psi attained 185 seconds; 5 nitrogen bottles avg 2050 psi.Wittiness of test waived by AOGCC Rep. Louis Grimaldi on 8-29-14 @ 10:20 hrs. 09/01/2014 Finish BOPE test. P/U&rack back 45 stands of 5" DP. P/U BHA 3&single in with DP. Perform casing psi test. Drill out shoe track&20'of new hole. Perform FIT. Displace well to 9.5 LSND mud system. 00:00 00:30 0.50 0 0 SURFA( WHDBO BOPE P PJSM. Continue initial BOPE test. Conduct draw down test on Super chokes, manual choke, and hydraulic.good. 00:30 01:30 1.00 0 0 SURFA( WHDBO RURD P Rig down testing equipment, blow down choke manifold, kill lines, set Cameron long wear bushing. 10"ID. 01:30 02:30 1.00 0 0 SURFA( CEMEN-RURD P Install bell guide on top drive, set mouse hole, SIMOPS: load 5"drill pipe in pipe shed. 02:30 06:45 4.25 0 0 SURFA( CEMEN-PULD P PJSM. Pick up 5"DP via the mouse holeand stand back 45 stands. 06:45 08:00 1.25 0 0 SURFA( CEMEN PULD P Lay down mouse hole, pick up BHA components via the beaver slide to rig floor. SIMOPS: load and strap 33 stands 5"DP. 08:00 09:30 1.50 0 97 SURFA( CEMEN-PULD P PJSM. Make up BHA. Review well control policy with non shearable tools in the stack. Make up BHA to 97'. 09:30 10:15 0.75 97 97 SURFA( CEMEN-RURD P PJSM. Loading nuclear sources. Time/Distance/shielding. Load the nukes. 10:15 11:15 1.00 97 205 SURFA( CEMEN PULD P Continue to make up BHA as per DD. 11:15 12:00 0.75 205 1,007 SURFA( CEMEN-PULD P Trip in the hole with singles out of the pipeshed. P/U Wt=70k 12:00 14:45 2.75 1,007 4,750 SURFA( CEMEN"PULD P PJSM-Continue to pick up 5"drill pipe from 1,007'MD to 4,750'MD 14:45 15:30 0.75 4,750 4,750 SURFA( CEMEN CIRC P Circulate and condition mud.until 9.8 ppg in/out. 15:30 16:45 1.25 4,750 4,750 SURFA( CEMEN PRTS P PJSM-RU test equip. and chart recorder. Perform casing test to 3000 psi./30 min. Lost 20 psi. in 30 min. Good test Page 7 of 29 • Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 19:30 2.75 4,750 4,851 SURFA( CEMEN-DRLG P Rig down test equip.Wash down and tag float collar @4,847'MD. Drlg. float collar.465 gpm=1325 psi, 80 rpm,Tq= 10-15K.WOB=20-24K. Flow out=58%. P/U=155K, S/0=75K, Rot=100K. Drill to 4,851 MD.Work bit through float collar. 19:30 20:00 0.50 4,851 4,938 SURFA( CEMEN DRLG P Drlg. firm cement. from 4,851' MD to 4,938' MD. Tag float shoe.465 gpm=1325 psi, 80 rpm, Tq= 10-15K. WOB=20-24K. Flow out=58%. P/U=155K, S/O=75K, Rot=100K. 20:00 21:00 1.00 4,938 4,950 SURFA( CEMEN DRLG P Orig. float shoe @ 4,938' MD. Wash down to 4,950'MD.465 gpm=1350 psi, 80 rpm, Tq=8-14K.WOB= 12-14K. Flow out=59%. P/U=155K, S/0=60K, Rot=97K. 21:00 21:15 0.25 4,950 4,970 SURFA( CEMEN DDRL P Drlg new formation 4,950' MD to 4,970'MD. 465gpm=1350 psi, 80 rpm, Tq=8-14K.WOB= 12-14K. Flow out=59%. P/U=155K, S/0=60K, Rot=97K. 21:15 21:45 0.50 4,970 4,970 SURFA( CEMEN CIRC P CBU @4,970' MD. 500 gpm= 1350 psi. Rotate and reciprocate 60 rpm Tq=8-13K, P/U= 105K 21:45 22:45 1.00 4,970 4,970 SURFA( CEMEN-FIT P Rig up and perform FIT.Test mud wt=9.8 ppg. EMW= 14.1 ppg. Rig down test equipment. 22:45 23:45 1.00 4,970 4,970 INTRM1 DRILL CIRC P Displace well w/9.6 ppg LSND mud. 460 gpm=950 psi. 23:45 00:00 0.25 4,970 4,970 INTRM1 DRILL CIRC P Conduct SPR's @4,941'MD, 3,256' TVD, MW 9.6 ppg, 23:45 hrs. #1 @30 spm=190 psi @ 40 spm=250 psi #2 @ 30 spm=190 psi @ 40 spm=250 psi 39/02/2014 Drill intermediate hole section from 4,970' MD to 7,248' MD.4,225'TVD 00:00 00:30 0.50 4,970 4,970 INTRM1 DRILL DISP P Continue to displace well to 9.6 ppg LSND.460 gpm=950 psi. 00:30 06:00 5.50 4,970 5,542 INTRM1 DRILL DDRL P DrIg from 4,970'MD to 5,542'MD. TVD=3,498',ADT=3.86,Total jar hrs=45.34, Bit hrs=4.11, P/U=115K, S/0=95K, Rot=105K,Tq on=7K,Tq off=4-5K, ECD=10.61 ppg, Flow out=62%,WOB=5-14K, RPM=120, GPM=625, SPM=147, SPP= 1700 psi, Max gas=155 units. Page 8 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 5,542 6,135 INTRM1 DRILL DDRL P DrIg from 5,542' MD to 6,135' MD. TVD=3,749',ADT=4.05,Total jar hrs=49.39, Bit hrs=8.16, P/U=120K, S/0=95K, Rot=106K,Tq on=10K, Tq off=4-5K, ECD=11.0 ppg, Flow out=65%, WOB=10-15K, RPM=120, GPM=650, SPM=153, SPP=2090 psi, Max gas=79 units. SPR's @ 5,580' MD, TVD=3,514', MW=9.6 ppg. 06:30 hrs. #1 @ 30 spm=250 psi @ 40 spm=300 psi #2©30 spm=230 psi @ 40 spm=300 psi. 12:00 18:00 6.00 6,135 INTRM1 DRILL DDRL P DrIg from 6,135'MD to 6,784'MD. TVD=4,025',ADT=4.14,Total jar hrs=53.53, Bit hrs=12.30, P/U=132K, S/0=100K, Rot=114K, Tq on=9K, Tq off=4-5K, ECD=11.87 ppg, Flow out=66%,WOB=10-13K, RPM=120, GPM=675, SPM=160, SPP=2450 psi, Max gas=16 units. SPR's©6,504' MD,TVD=3,905', MW=9.8 ppg. 15:45 hrs. #1 @ 30 spm=300 psi @ 40 spm=390 psi #2 @ 30 spm=290 psi©40 spm=400 psi. 18:00 00:00 6.00 6,784 7,248 INTRM1 DRILL DDRL P DrIg from 6,784'MD to 7,248'MD. TVD=4,225',ADT=3.36,Total jar hrs=56.89, Bit hrs=15.66, P/U=140K, S/0=101K, Rot=117K, Tq on=10K,Tq off=4-6K, ECD=11.81 ppg, Flow out=67%,WOB=8-15K, RPM=160, GPM=704, SPM=165, SPP=2700 psi, Max gas=16 units. SPR's @ 6,967' MD,TVD=4,103', MW=9.8 ppg. 21:45 hrs. #1 @ 30 spm=320 psi @ 40 spm=390 psi #2 @ 30 spm=330 psi @ 40 spm=400 psi. Kick w/drilling drill CRT=62 sec. 09/03/2014 Drill intermediate hole section from 7,248' MD to 9,747' MD. 5,273'TVD Page 9of29� • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 7,248 7,895 INTRMI DRILL DDRL P DrIg from 7,248' MD to 7,895' MD. TVD=4,500',ADT=4.51,Total jar hrs=61.40, Bit hrs=20.17, P/U=145K, S/0=109K, Rot=120K, Tq on=12K, Tq off=5-6K, ECD=11.70 ppg, Flow out=68%,WOB=10-15K, RPM=160, GPM=700, SPM=164, SPP=2960 psi, Max gas=34 units. SPR's @ 7,703'MD, TVD=4,420', MW=9.8 ppg. 04:30 hrs. #1 @ 30 spm=320 psi @ 40 spm=420 psi #2 @ 30 spm=330 psi @ 40 spm=400 psi. 06:00 12:00 6.00 7,895 8,487 INTRMI DRILL DDRL P DrIg from 7,895'MD to 8,487'MD. TVD=4,749',ADT=3.68, Total jar hrs=65.08, Bit hrs=23.85, P/U=150K, S/0=110K, Rot=125K, Tq on=13K, Tq off=7K, ECD=11.72 ppg, Flow out=67%,WOB=14K, RPM=160, GPM=700, SPM=164, SPP=3000 psi, Max gas=29 units. SPR's @ 8,266'MD,TVD=4,655', MW=9.8 ppg. 09:30 hrs. #1 @ 30 spm=350 psi @ 40 spm=420 psi #2 @ 30 spm=340 psi @ 40 spm=390 psi. 12:00 18:00 6.00 8,487 9,134 INTRM1 DRILL DDRL P DrIg from 8487' MD to 9,134' MD. TVD=5,021',ADT=4.08,Total jar hrs=69.16, Bit hrs=27.93, P/U=166K, S/O=112K, Rot=131K, Tq on=13-14K,Tq off=7-10K, ECD=11.77 ppg, Flow out=68%, WOB=13-18K, RPM=160, GPM=703, SPM=164, SPP=3200 psi, Max gas=99 units. SPR's @ 8,729'MD,TVD=4,850', MW=9.8 ppg. 14:00 hrs. #1 @ 30 spm=340 psi @ 40 spm=410 psi #2 @ 30 spm=330 psi @ 40 spm=420 psi. 1.._ Page 10 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 9,134 INTRM1 DRILL DDRL P DrIg from 9,134' MD to 9,747'MD. TVD=5,273',ADT=4.16,Total jar hrs=73.32, Bit hrs=32.09, P/U=163K, S/O=115K, Rot=134K, Tq on=12-13K, Tq off=7-10K, ECD=11.29 ppg, Flow out=68%, WOB=5-8K, RPM=160, GPM=704, SPM=165, SPP=3100 psi, Max gas=253 units. Pump hi-vis sweep every 500'. Minimal increase in cuttings. SPR's @ 9,283' MD,TVD=5,093', MW=9.8 ppg. 18:30 hrs. #1 @ 30 spm=400 psi @ 40 spm=490 psi #2 @ 30 spm=410 psi @ 40 spm=480 psi. 09/04/2014 Drill intermediate hole section from 9,747' MD to 11,876'MD.6,042'TVD 00:00 06:00 6.00 9,747 10,303 INTRM1 DRILL DDRL P DrIg from 9,747'MD to 10,303' MD. TVD=5,514',ADT=4.34,Total jar hrs=77.66, Bit hrs=36.43, P/U=168K, S/O=124K„Rot=140K, Tq on=12-14K,Tq off=8K, ECD=11.30 ppg, Flow out=66%, WOB=8-10K, RPM=160, GPM=700, SPM=163, SPP=3360 psi, Max gas=133 units. SPR's @ 9,831'MD,TVD=5,312', MW=9.9 ppg. 00:43 hrs. #1 @ 30 spm=380 psi @ 40 spm=460 psi #2 @ 30 spm=380 psi©40 spm=470 psi. 06:00 12:00 6.00 10,303 10,930 INTRM1 DRILL DDRL P Drlg from 10,303' MD to 10,930' MD. TVD=5,749',ADT=3.74,Total jar hrs=81.40, Bit hrs=40.17, P/U=171K, S/O=119K„Rot=138K, Tq on=15K, Tq off=10K, ECD=11..33 ppg, Flow out=68%,WOB=10-11K, RPM=160, GPM=700, SPM=164, SPP=3525 psi, Max gas=424 units. SPR's @ 10,857' MD,TVD=5,728', MW=10 ppg. 11:15 hrs. #1 @ 30 spm=420 psi©40 spm=500 psi #2 @ 30 spm=390 psi @ 40 spm=500 psi. Page 11 of 291 Time Logs a Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 10,930 11,500 INTRM1 DRILL DDRL P DrIg from 10,930'MD to 11,500'MD. TVD=5,963',ADT=4.42, Total jar hrs=85.82, Bit hrs=44.59, P/U=189K, S/O=124K„Rot=147K, Tq on=15-16K, Tq off=10-11 K, ECD=11..39 ppg, Flow out=67%, WOB=9-11K, RPM=160, GPM=703, SPM=165, SPP=3600 psi, Max gas=223 units. SPR's @ 11,320'MD,TVD=5,915', MW=10.1 ppg. 16:20 hrs. #1 ©30 spm=400 psi @ 40 spm=500 psi #2 ©30 spm=400 psi @ 40 spm=500 psi. 18:00 00:00 6.00 11,500 11,876 INTRM1 DRILL DDRL P DrIg from 11,500'MD to 11,876'MD. TVD=6,042',ADT=4.23, Total jar hrs=90.05, Bit hrs=48.82, P/U=195K, S/0=120K„Rot=147K, Tq on=14-16K, Tq off=11-12K, ECD=11..30 ppg, Flow out=67%, WOB=9-14K, RPM=170, GPM=701, SPM=165, SPP=3640 psi, Max gas=343 units. SPR's @ 11,873' MD, TVD=6,042', MW=10.2 ppg. 23:45 hrs. #1 @ 30 spm=400 psi @ 40 spm=490 psi #2 @ 30 spm=390 psi @ 40 spm=480 psi. Kick w/tripping drill. ©23:30 hrs. CRT=75 sec 09/05/2014 Drill intermediate hole section to TD @12,570 MD. 6,161'TVD. Circulate and condition mud. Pump out of hole to 9,843' MD.. 00:00 06:00 6.00 11,876 12,269 INTRM1 DRILL DDRL P Drlg from 11,876' MD to 12,269' MD. TVD=6,129',ADT=4.36, Total jar hrs=94.41, Bit hrs=53.18, P/U=196K, S/O=124K„Rot=149K, Tq on=15-16K, Tq off=13K, ECD=11..31 ppg, Flow out=66%, WOB=8-10K, RPM=160, GPM=706, SPM=165, SPP=3550 psi, Max gas=386 units. SPR's @ 11,873'MD, TVD=6,042', MW=10.2 ppg. 23.45 hrs. Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 12,269 12,515 INTRM1 DRILL DDRL P DrIg from 12,269'MD to 12,515'MD. TVD=6,156', ADT=5.19,Total jar hrs=99.60, Bit hrs=58.37, P/U=196K, S/O=119K„Rot=146K, Tq on=17-18K, Tq off=12.5K, ECD=11..21 ppg, Flow out=66%, WOB=7-11K, RPM=160, GPM=706, SPM=166, SPP=3400 psi, Max gas=436 units. SPR's @ 12,340' MD,TVD=6,143', MW=10.2 ppg. 07:37 hrs. #1 @ 30 spm=410 psi @ 40 spm=500 psi #2 @ 30 spm=400 psi @ 40 spm=480 psi. 12:00 13:30 1.50 12,570 12,570 INTRM1 DRILL DDRL P DrIg from 12,515'MD to 12,570' MD. TVD=6,161',ADT=1.15, Total jar hrs=100.75, Bit hrs=59.52, P/U=203K, S/O=116K„Rot=146K, Tq on=17-18K, Tq off=12.5K, ECD=11..21 ppg, Flow out=66%, WOB=7-11K, RPM=160, GPM=706, SPM=166, SPP=3400 psi, Max gas=40 units. SPR's @ 12,570'MD, TVD=6,161', MW=10.2 ppg. 15:00 hrs. #1 @ 30 spm=350 psi @ 40 spm=440 psi #2 @ 30 spm=350 psi @ 40 spm=430 psi. 13:30 16:15 2.75 12,570 12,570 INTRM1 CASING CIRC P Circulate and condition mud. Rotate and reciprocate. 160 rpm, 709 gpm, ECD=11.0. P/U=136K, S/O=138, Tq=15K 16:15 16:45 0.50 12,570 12,570 INTRM1 CASINGOWFF P Monitor well. Static 16:45 00:00 7.25 12,570 9,843 INTRM1 CASING TRIP P Pump out of hole. Pull from 12,570' MD to 11,694' MD @ 600 ft/hr, Pull from 11,694' MD to 10,768' MD @ 800 ft/hr. Pull from 10,768'MD to 9,843' MD @ 1200 ft/hr.2.5 bpm, SPP=500 psi, Flow out=15%. P/U=170K, S/0=102K. Calc. disp=22.8,Act disp=36.9 09/06/2014 Con't to pump out of hole.to surface shoe. POH on elevators. L/D BHA.. Change and test rams. Make hanger dummy run. 00:00 08:45 8.75 9,843 INTRM1 CASING TRIP P Pump out of hole from 9,843' MD to 4,9335' MD. Pull at 1200 ft/hr from 9,843'MD to 7,600' MD. Pull from 7,600'MD to 4,935' MD @ 1500 ft/hr. 3 bpm. 600 psi. Flow out= 16%. P/U=111 K, S/0=76K. Calc fill=63 bbls.Act fill=98 bbls. 08:45 11:30 2.75 4,935 4,935 INTRM1 CASING CIRC P CBU @ 4,935'MD. 716 gpm, 2350 psi, 120 rpm.Tq=3K. ECD=10.6. Flow out=64%. P/U=100K, S/0=94K 11:30 12:00 0.50 4,935 4,395 INTRM1 CASINGOWFF P Monitor well. Page 13 of 29 Time Logs • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 12:45 0.75 4,395 4,935 IINTRM1 CASING OWFF I P Monitor well. Static 12:45 13:30 0.75 4,935 4,472 INTRM1 CASING TRIP P Pump out of hole from 4,935'MD to 4,472'MD.2.5 bpm, 150 psi, Flow out=24%, 13:30 16:15 2.75 4,472 760 INTRMI CASING TRIP P POOH on elevators from 4,472'MD to 760'MD. Pump dry job @ 4,010' MD. 16:15 16:30 0.25 760 760 INTRMI CASING OWFF P Monitor well. Static 16:30 18:15 1.75 760 205 INTRM1 CASING TRIP P POOH. Stand back HWDP and jar. 18:15 19:00 0.75 205 0 INTRM1 CASING PULD P Lay down BHA as per SLB. Unload nuke sources. Total cal fill=47.18, Total act fill=47.6 bbls for trip from 4,935'to 0'. 19:00 19:30 0.50 0 0 INTRM1 CASING RURD P Clean and clear rig floor. 19:30 20:45 1.25 0 0 INTRM1 CASING OTHR P R/U and flush BOP. Pull wear ring. Perform dummy run w/7 5/8"csg. hanger. 20:45 22:30 1.75 0 0 INTRM1 CASING RURD P Change upper VBR's to 7 5/8"fixed bore rams. 22:30 23:00 0.50 0 0 INTRMI CASING BOPE P Set test plug. Rig up test equip. 23:00 23:45 0.75 0 0 INTRMI CASING BOPE P Test annular and 7 5/8"rams to 250 psi./5 min. 3500 psi./5 min. 23:45 00:00 0.25 0 0 INTRM1 CASING BOPE P Rig down test equip. Pull test plug. 09/07/2014 Cut and slip drilling line. Rig up to run 7 5/8"csg. Run 7 5/8"intermediate csg.to 7,409'MD. 00:00 01:30 1.50 0 0 INTRM1 CASING RURD P PJSM, Mobilize Volant CRT to rig floor and make up to top drive. 01:30 02:30 1.00 0 0 INTRM1 CASING RURD P Mobilize casing equipment to rig floor and rig up. 02:30 03:45 1.25 0 0 INTRM1 CASING SLPC P PJSM, slip and cut drill line(107'). 03:45 04:30 0.75 0 0 INTRM1 CASING RURD P Continue to rig up to run casing. 04:30 05:00 0.50 0 0 INTRM1 CASING SFTY P PJSM-Run 7-5/8"casing. 05:00 05:45 0.75 0 177 INTRM1 CASING PUTB P Make up shoe track, baker-loc to joint#4, check floats(good). 05:45 08:15 2.50 177 1,130 INTRM1 CASING PUTB P Run in hole with 7-5/8"39#TN-110 HYD 563 casing from 177' MD to 1130'MD. 08:15 12:00 3.75 1,130 3,021 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 3021' MD;Actual=28bbls Calculated=30bbls. 12:00 16:15 4.25 3,021 4,930 INTRMI CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 4,930' MD; 16:15 17:45 1.50 4,930 4,930 INTRMI CASING CIRC P CBU @ 10 3/4"shoe. Stage up pumps from 1 bpm to 6 bpm. 150 psi-375 psi,42%flow out @ 6 bpm. 0 losses 17:45 23:30 5.75 4,930 7,409 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 7,409' MD. P/U=160K S/O=110K. Disp.for tour. Cal=78.5 bbls Act.=70.1 bbls Page 14 of 29 Time Logs , • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 7,409 7,409 INTRM1 CASING CIRC P CBU @ 7,409' MD. Stage pumps up from 1 bpm to 4 bpm, 300-400 psi. Flow out=43%.@ 4 bpm 09/08/2014 Run intermediate casing to 12,558'. Circ and cond mud. Rig up to cement. 00:00 01:15 1.25 7,409 7,409 INTRMI CASING CIRC P CBU @ 7,409'MD. Stage pumps up from 4 bpm to 5 bpm, 450 psi. Flow out=41%.@ 5 bpm. P/U=153K S/0=105K 01:15 05:30 4.25 7,409 9,128 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 9,128' MD. 05:30 07:00 1.50 9,128 9,128 INTRM1 CASING CIRC P CBU @ 9128'MD. Stage pumps up to 5 bpm,425 psi. Flow out=40% 07:00 08:30 1.50 9,128 9,128 INTRMI CASING RGRP T Secure rig floor. Investigate and repair dropped dowel from top drive. Two bolts securing stand jump cylinder on off driller side failed causing dowel to fall to rig floor. 08:30 12:00 3.50 9,128 10,514 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 10,514' MD..Act. disp= 102.5 bbls. Calc disp=107 bbls 12:00 15:00 3.00 10,514 11,785 INTRMI CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 11,785' MD.. Slack weight decreased 40K. Decisison made to CBU. 15:00 17:00 2.00 11,785 11,785 INTRM1 CASING CIRC P CBU @11,785 MD. Stage pumps up to 5 bpm. 1 bpm=400 psi w/slight returns @ flow line. 5 bpm=725 psi w/43%flow out/no losses 17:00 18:45 1.75 11,785 12,332 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 12,332' MD.. Slack weight decreased 50K. Decisison made to pump remaining 5 jts to bottom.. 18:45 20:00 1.25 12,332 12,558 INTRM1 CASING PUTB P Continue to run in the hole with 7-5/8"29.7#L-80 HYD 563 to 12,332' MD.. pumping 2 bpm @450 psi. M/U hanger and landing jt. Land hanger on depth. Total calc. disp for casing run=133 bbls.Act disp=119.3 P/U=265K 5/0=110K 20:00 23:00 3.00 12,558 12,558 INTRM1 CASING CIRC P Circulate and condition mud for cement job. Stage pumps up from 2 bpm to 6 bpm.450 psi to 700 psi. Flow out=42%@ 6bpm. Reciprocate 25'stroke. P/U=235K S/O=110K 23:00 00:00 1.00 12,558 12,558 INTRMI CEMEN-RURD P Rig down Volant CRT. Blow down top drive. R/U cement head. 09/09/2014 Cement Intermediate in place,WOC, FP OA w/95±bbls of Iso Therm. Lay down 5"DP in preparation to drill production zone. 00:00 00:15 0.25 12,558 12,558 INTRM1 CEMEN-RURD P Continue to rig up cement head Page 15 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 00:30 0.25 12,558 12,558 INTRM1 CEMEN-CIRCP PJSM on cementing. Continue to circ and reciprocate. 6 bpm, 725 psi. Flow out=35%. P/U=250K 5/0=119K 00:30 00:45 0.25 12,558 12,558 INTRM1 CEMEN-PUCM P Pump 5 bbls CW 100. Pressure test lines and pump trip outs. 1000 psi low/4000 psi high 00:45 03:45 3.00 12,558 12,558 INTRM1 CEMEN-PUCM P Pump 35 bbls CW 100 @ 4.9 bpm, 570 psi., followed by 40 bbls of Mud Push II @ 3 bpm, 417 psi.. Drop bottom plug. Pump 76 bbls 15.8 ppg Class G cmt. @ 2 to 4.5 bpm 200 to 500 psi. Pump unit having problems delivering cmt. from silo to mix tub. Stop and batch mix cmt. Continue pumping 15.8 ppg Class G cmt to 84 bbls total pumped.2bpm 220 psi. Stop to batch mix remaining cement. Pump remaining cmt. for a total of 94 bbls. Drop top plug. Pump 10 bbls water. Displace cement with rig pumps. Pump total of 560.9 bbls. 6 bpm for 550 bbls. Slow pump to 3 bpm final 5 bbls. Reciprocate entire job with full returns. Did not bump plug. Final pressure @ 3 bpm=600 psi. 03:45 12:00 8.25 12,558 12,558 INTRM1 CEMEN WOC P Clean rig and work on mud pump#2 while WOC 12:00 13:45 1.75 12,558 12,558 INTRM1 CEMEN RURD P PJSM, bleed off pressure on csg to check floats and cmt integrity- Good. NFT for 30 minutes while rigging down cmt head and landing joint. Change over equipment. 13:45 15:45 2.00 12,558 0 INTRM1 WHDBO WWSP P Set pack off as per Cameron Rep and test same at 250/5,000 psi for 10 minutes. -Witnessed by CPAI rep. /Simops RU to lay down 5"DP via the mouse hole. 15:45 18:00 2.25 0 0 INTRM1 CEMEN-PULD P PJSM, Lay down 67 jts of 5"DP, 17 jts of 5"HWDP and Drlg jars via mouse hole. Page 16 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 0 INTRM1 CEMEN-FRZP P Held PJSM with Little Red Services on Freeze protecting 10.75"x 7.625" Annuli with 94.5 bbls of MI IsoTherm packer fluid. RU and fluid pack treating lines, PT @ 4,500 psi-Good Test. Begin treating process with remaining fresh water, Establishing an injection rate @.5 bpm @ 200 psi and break over @ 650 psi with 5 bbls pumped away increase to 3 bpm and clear annuli with another 225 bbls pumped. Swap over to Iso Therm(MI Product)and freeze protect with 94.5 bbls of MI IsoTherm packer fluid @ 3 bpm with 700 ICP and 1,400 FCP. SWI, SICP=600 psi, RD and release LRS. Sim ops conducted during FP-(Continue to lay down 237 joints of 5"DP) 09/10/2014 Continue to lay down 5"DP, Change over equipment for 4"XT-39 DP, Change upper rams from 7-5/8 to 2-7/8"x 5"VBR's and conduct full BOP test. 00:00 00:30 0.50 0 0 INTRM1 CEMEN-SVRG P Service and Lubricate rig 00:30 03:45 3.25 0 0 INTRM1 CEMEN-PULD P Contninue to lay down remaining 87 jts of 5"DP via the mouse. Clean and clear rig floor. 03:45 06:00 2.25 0 0 INTRM1 CEMEN-RURD P PJSM, Change out saver sub to XT-39. Sim Ops--off load 5' DP from pipe shed and reload with 4"DP 06:00 08:00 2.00 0 0 INTRM1 CEMEN OTHR P Cont to load pipe shed with 4"XT-39 drill pipe. Strap and drift drill pipe. 08:00 15:00 7.00 0 0 INTRM1 CEMEN PULD P PJSM, pick up 4"XT-39 drill pipe from pipe shed and stand back in derrick, Picked up a total of 210 joints,70 stands, 15:00 23:45 8.75 0 0 INTRM1 WHDBO BOPE P PJSM, Open UPR's and change rams over to 2-7/8 x 5"VBR's. RU and Conduct bi weekly BOP test at 250/3,500 psi w/3-1/2",4", and 4.5"Test joints. 24 Notice was given to AOGCC on 9-8-14 @ 09:14 hrs and Right to witness was waived by AOGCC John Crisp on 9-9-14 @ 22:00 hrs 23:45 00:00 0.25 0 0 INTRM1 WHDBO RURD P Begin RD testing equipment. 39/11/2014 Continue to RD BOP Test equip. PU and RIH w/BHA#4(6-1/2"Drlg Assy)to 12,229-ft. Gather parameters and PT intermediate csg string. Drill out shoe track and 20-ft of new hole. Condition Hole volume for LOT. 00:00 00:45 0.75 0 0 INTRM1 WHDBO RURD P PJSM, Cont to R/D BOP testing equipment, blow down choke and kill line. Set wear bushing 00:45 01:00 0.25 0 0 INTRM1 CEMEN-PULD P Pick up SLB tools from beaver slide to rig floor. 01:00 02:45 1.75 0 185 INTRM1 CEMEN-PULD P PJSM, M/U BHA#4 as per SLB rep, Power Drive, Periscope and MicroScope. Page 17 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:15 0.50 185 185 INTRM1 CEMEN-PULD P PJSM, load nuclear sources as per MWD hand. 03:15 04:15 1.00 185 415 INTRM1 CEMEN-PULD P Cont to P/U BHA#4, NMFX,well commander, HWDP and jars. 04:15 14:45 10.50 415 12,335 INTRM1 CEMEN-PULD P Continue to RIH picking up 4"drill pipe w/6.5"Production DrIg BHA from 415-ft to 12,335-ft MD. PU wt= 165k, SO wt=80k. 14:45 17:15 2.50 12,335 12,335 INTRM1 CEMEN-PRTS P CBU in preparation for casing test. 10.2+MW in/out. Circulate at 235 gpm @ 2,250 psi with 47%return. RU test equipment and PT 7-5/8 Intermediate string to 3,500 psi for 30 minutes and chart. Rig down test equipment. 17:15 18:00 0.75 12,335 12,471 INTRM1 CEMEN COCF P Obtain SPR's 12,425-ft/6,146-ft TVD, 10.2+MW@ 17:38 hrs #1 @ 20 spm @ 830 psi @ 30 spm @ 1090 psi #2 @ 20 spm @ 810 psi @ 30 spm @ 1100 psi Wash down from 12335-ft to 12,471-ft MD and tag float collar. 18:00 21:00 3.00 12,471 12,590 INTRM1 CEMEN DRLG P Drill up wiper plug and FC @ 12,471-ft and fell through with 30 minutes. Continue to drill out to shoe @ 12,560-ft. Drill out shoe to 12,565-ft in 25 minutes. Wipe shoe for 5-ft and return to drlg OH from 12,565-ft to 12,590-ft MD,TVD= 6164-ft,ART= .33,Total Jar hrs= 121.29, Bit hrs= .33, PU wt= 165k, SO wt=75k, ROT wt= 105k,TQ on = 15k,TQ Off= 14.5, ECD= 11.64, Flow out=43%,WOB=3-10k, RPM=80, GPM =52, and SPP= 2,250. 21:00 22:45 1.75 12,590 12,590 INTRM1 CEMEN-CIRC P Circulate and condition mud volume to 10.2+ In/Out for LOT@ 223 gpm @ 2,250 psi w/41%F/O. While reciprocating. 22:45 23:00 0.25 12,590 12,520 INTRM1 CEMEN RGRP T H2S Gas alarm system malfunctioning,decision was made to pull inside shoe and fix alarm before LOTias conducted 23:00 00:00 1.00 12,520 12,520 INTRM1 CEMEN-CIRCT Continue to circulate and condition well @ 12,520-ft @ 224 gpm @ 2,225 psi w/45% F/0. While trouble shooting Gas alarm system. 39/12/2014 Trouble shoot Gas monitoring system. Conduct leak off test-EMW= 14.6 ppg. Drill production section f/ 12,590-ft MD to 13,276-ft MD, Back ream to 12,524-ft due to gas alarm system failure. Page 18 of 29 Time Logs 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 12,520 12,520 INTRM1 CEMEN'RGRP T Monitor well on Trip tank while trouble shoot rig gas alarm system due to Station#5 malfunctioning (Shaker H2S alarm) w/no gas verification using hand held for verification. System was trouble shot 6 hrs previously and adjustments were made due to High LEL reported in a barrier tested system. Changed out gas panel controller and retest gas alarms. 04:00 05:30 1.50 12,520 12,590 INTRM1 CEMEN-CIRCP M/U 1 stand, circulate and condition hole for FIT/LOT, pump @ 230 gpm=2475 psi, 70 rpm's w/15K tq. ECD= 11.72 ppg EMW. P/U= 106K, 5/0103K. 05:30 05:45 0.25 12,590 12,520 INTRM1 CEMEN-TRIP P Stand back one stand and blow down top drive. 05:45 06:15 0.50 12,520 12,520 INTRM1 CEMEN-OWFF P OWFF, static. 06:15 06:45 0.50 12,520 12,520 INTRM1 CEMEN-SFTY T Conduct safety meeting on continuing operations using handheld gas meter in the possum belly. Discussed good communication with driller and pit watcher. Ensuring gas meter does not get wet and getting monitored properly. 06:45 07:30 0.75 12,520 12,520 INTRM1 CEMEN-RURD P R/U for FIT/LOT. Flood lines with mud and ensure no air trapped in circ lines. 07:30 08:15 0.75 12,520 12,520 INTRM1 CEMEN-LOT P Perform FIT to 14.6 ppg EMW, 1400 _ psi on surface w/10.2 ppg MW. 08:15 09:00 0.75 12,520 12,520 INTRM1 CEMEN'RURD P R/D testing equipment, blow down circ line and kill line. 09:00 09:15 0.25 12,520 12,520 PROD1 DRILL SFTY P Hold PJSM on displacing well to 10.5 ppg Flo-Pro NT. Discussed ensuring all permits are filled out properly and performing crew change during displacement. 09:15 11:15 2.00 12,520 12,590 PROD1 DRILL DISP P Displace well f/LSND mud to Flo-Pro NT, 10.5 ppg. Pump@ 220 gpm= 2750 psi, 70 rpm's w/15K Tq. 11:15 12:00 0.75 12,590 12,590 PROD1 DRILL CIRC P Obtain SPR's and establish base line ECD's. 12:00 18:00 6.00 12,590 12,991 PROD1 DRILL DDRL P Drilling from 12,590-ft to 12,991-ft MD, 6,168-ft TVD,ART=3.98,ADT= 3.98. Total Jar hrs= 125.27. Bit hrs =4.31. PUwt= 154k, SOwt=80k and ROT wt 111k. TQ on= 13k, TQ off=9k. ECD= 12.04, F/O=40%, WOB=8-10k, RPM=80/140, GPM =241, SPM=56, PSI =2,675 Page 19 of 29 Time Logs I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 12,991 13,276 PROD1 DRILL DDRL P Drilling from 12,991-ft to 13,276-ft MD, 6,159-ft TVD,ART=2.07,ADT= 2.07. Total Jar hrs= 127.34. Bit hrs =4.31. PU wt= 153k, SO wt=80k and ROT wt 111k. TQ on= 13k, TQ off=9k. ECD= 12.04, F/O=41°i°, WOB=5-10k, RPM= 140, GPM= 240, SPM=56, PSI =2,700 21:00 00:00 3.00 13,276 12,524 PROD1 DRILL REAM T Back ream back from 13,276-ft to 12,524-f tMD @ 215 gpm,2,200 psi, 40 rpm's w/9.5k TQ due to Trouble shoot gas alarm system, 09/13/2014 Trouble shoot Gas monitoring system. RIH to 13,276-ft to 13,548-ftMD. Observed gas at surface, increase mud wt from 10.5 to 10.8 ppg and change the hole over. Back ream to 12,524-ft for Gas Alarm System failure and monitor well on trip tank. Repair gas alarm system. 00:00 03:15 3.25 12,524 12,524 PROD1 DRILL RGRP T PJSM, Trouble shoot gas alarm system and changed out gas panel controller. Circulate @ 215 gpm=2050 psi, 38%flow,20 rpm's w/8K Tq. P/U= 150K, 5/0=78K, ROT= 110K. 03:15 03:45 0.50 12,524 13,183 PROD1 DRILL TRIP T RIH f/12524' MD to 13183' MD. Actual displacement=4.3 bbls, Calculated displacement=3.78 bbls. 03:45 04:00 0.25 13,183 13,276 PROD1 DRILL REAM T Wash and ream to bottom f/13183' MD to 13276' MD. Pump @ 220 gpm=2200 psi, 39%flow, 50 rpm's w/10K Tq. Obtain SPR's. 04:00 07:00 3.00 13,276 13,548 PROD1 DRILL DDRL P Drilling from 13183'MD to 13548'MD ,6159-ft TVD,ART= 1.97,ADT= 1.97. Total Jar hrs= 129.31. Bit hrs =8.35. PU wt= 155k, SO wt=79k and ROT wt 114k. TQ on= 13k,TQ off= 11k. ECD= 11.90, F/O=39%, WOB=5-10k, RPM = 130, GPM= 240, SPM=56, PSI =2,610 07:00 12:00 5.00 13,548 13,278 PROD1 DRILL CIRC T Observed gas flow out 39%to 42%( 17%of LEL on hand held meter)gas alarm#5(H2S possum belly)and gas alarm#6(Methane possum belly)not working. Decision made to increase mud weight f/10.5 ppg to 10.8 ppg then POOH to shoe to repair gas alarms. Circulate and increase mud weight w/NaCa and Calcium Carbonate to 10.8 ppg. Pump @ 230 gpm=2500 psi, 39% flow, 80 rpm's w/8-12K Tq. Obtain SPR's @11:45w/10.8ppg MW. MP#1 20 spm=700 psi&30s pm= 1020 psi. MP#2=20 spm=710 psi& 30 spm= 1030 psi. 12:00 12:30 0.50 13,278 13,278 PROD1 DRILL OWFF T Monitor well(static)while holding PJSM on Back reaming back top the shoe. Page 20 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:15 1.75 13,278 12,524 PROD1 DRILL REAM T Back ream to the shoe from 13,278-ft to 12,524-ft @ 215 GPM @ 2,200 PSI,w/40 RPMS and 10K torque, returning at 40%. Downlink MWD Tool and Blow down top drive. 14:15 00:00 9.75 12,524 12,524 PROD1 DRILL RGRP T Trouble shoot and fix rig gas alarm detection system while monitoring the well via the trip tank. Sim ops- remove spinners for repair, prep the pipe shed overhead rail system for inspection. MP2 on DWKS, clean inside DWKS. Paint pump room, service high/low clutch system air valves. Remove idle rollers on skate system for repair. 09/14/2014 Repair gas alarm system and trip back to 13,548-ft and Alarms failed, POOH to Shoe and continue to repair alarm system. 00:00 10:30 10.50 12,524 12,524 PROD1 DRILL RGRP T Trouble shoot and fix rig gas alarm detection system while monitoring the well via the trip tank. Sim ops- prep the pipe shed overhead rail system for inspection. MP2 on DWKS, clean inside DWKS. Paint pump room, service high/low clutch system air valves. Remove idle rollers on skate system for repair. Replaced gas alarm main unit, sensors, heads and cable f/#5 and #6 sensors. Tested all stations on unit,good. 10:30 12:30 2.00 12,524 13,548 PROD1 DRILL TRIP T PJSM, RIH from 12,524-ft to 13,468-ft, Start washing and reaming to 13,548-ft @ 195 GPM @ 2,150 psi while rotating @ 100 RPM's w/ 111ft/Ibs TQshowing 43%flow returns. Alarms started going off again,decision was to pull back to the shoe. CBU at 226 GPM @ 2,650 psi while rotating @ 100 RPM w/11K torque. 12:30 12:45 0.25 13,548 13,548 PROD1 DRILL OWFF T Monitor well, Static, Obtain SPR's 12:45 15:15 2.50 13,548 12,524 PROD1 DRILL TRIP T Pump out of the from 13,548-ft to 12,524-ft at 215 GPM @ 2,100 psi. with 40% returns. Page 21 of 29 Time Logs 111/ Date From To Dur S. Depth E.Depth Phase -Code Subcode T Comment 15:15 00:00 8.75 12,524 12,524 PROD1 DRILL RGRP T Trouble shoot Gas monitoring system. Monitor well via trip tank. Sim ops, Remove guards/draworks and inspect spline Gap along with clutch clearance. Install IR Spinner assy. Paint the centrifigual and pump room, along with the boiler room extension. Continue to prep the pipe shed bridge crane rails for inspection. Weld pipe shed air heater skid and install draw works guards. 09/15/2014 Repair gas alarm system and trip back to 13,548-ft and Continue to drill Production section to 15,084-ft MD 6,207-ft TVD 00:00 07:00 7.00 12,524 12,524 PROD1 DRILL RGRP T PJSM, Cont to work on gas alarms. Replaced some of the cable,tested alarms, OK. Kelly up and pump @ 240 gpm=2650 psi and move pipe to test alarms, alarms malfunctioned. Replaced move cables and re-tested, OK. Kelly up and pump @ 200 gpm=2400 psi and move pipe to test alarms, alarms worked properly. 07:00 07:30 0.50 12,524 13,468 PROD1 DRILL TRIP T RIH f/12524' MD to 13468' MD. Actual displacement=5.4 bbls, Calculated displacement=6.1 bbls. 07:30 07:45 0.25 13,468 13,548 PROD1 DRILL REAM T Wash and ream f/13468'MD to 13548' MD, pump @ 240 gpm=2700 psi,40%flow, 130 rpm's w/11K Tq. 07:45 12:00 4.25 13,548 13,879 PROD1 DRILL DDRL P Drilling from 13548'MD to 13879' MD , TVD 6178', ART=2.48,ADT= 2.48. Total Jar hrs= 131.79. Bit hrs =10.83. PU wt= 170k, SO wt=73k and ROT wt 111k. TQ on= 13.5k, TQ off= 12k. ECD= 11.63, F/O= 41%,WOB=5-7k, RPM= 140, GPM=240, SPM=56, PSI = 2,810 Obtain SPR's @ 13546'MD TVD= 6160, MW 10.8 ppg, 07:45 hours MP#1: 20 spm=770 psi. 30 spm= 1140 psi MP#2;20 spm=810 psi, 30 spm= 1120 psi. 12:00 18:00 6.00 13,879 14,507 PROD1 DRILL DDRL P Drlg from 13,879-ft MD to 14,507-ft MD, TVD=6,195-ft, ART=4.26, ADT=4.26. Total jar hrs= 136.05, Bit hrs= 15.09, PU wt= 166k, SO wt=72k, ROT wt= 110k. TQ on= 13k,TQ off=9.5k. ECD= 12.57. Flow out=41%,WOB=5- 10k, RPM= 140, GPM=240, SPP= 2,850 Page 22 of 29 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 14,507 15,084 PROD1 DRILL DDRL P DrIg from 14,507-ft MD to 15,084-ft MD,TVD=6,207-ft, ART=3.78, ADT=3.78. Total jar hrs= 139.83 Bit hrs= 18.87 PU wt= 170k, SO wt =70k, ROT wt= 111 k. TQ on= 13k,TQ off=10k. ECD= 12.6. Flow out=41%, WOB=7- 11k, RPM= 140, GPM =240, SPP=2,905 09/16/2014 Directional drilled production section from 15084'- 17489'MD, 6251'TVD. 00:00 06:00 6.00 15,084 15,644 PROD1 DRILL DDRL P DrIg from 15084'MD to 15644 MD, TVD=6217', ART=3.88,ADT=3.88. Total jar hrs= 143.71 Bit hrs=22.75 PU wt= 185k, SO wt=65k, ROT wt = 110k. TQ on= 14k, TQ off=12k. ECD= 12.82. Flow out=39%,WOB =7- 10k, RPM = 140, GPM=240, SPP=2,900 Obtain SPR's @ 15169'MD TVD= 6212', MW 10.8 ppg 00:30 hours MP#1=20 spm=750 psi, 30 spm= 1080psi. MP#2: 20 spm=810 psi, 30 spm= 1070 psi. 06:00 12:00 6.00 15,644 16,212 PROD1 DRILL DDRL P Drlg from 15644'MD to 16212 MD, TVD=6224', ART=4.15,ADT=4.15. Total jar hrs= 147.86 Bit hrs=26.90 PU wt= 185k, SO wt=64k, ROT wt = 108k. TQ on= 14k, TQ off=12k. ECD= 12.83. Flow out=39%,WOB =8-10k, RPM = 140, GPM=240, SPP=3,025 Spill Drill CRT= 148 sec @ 08:30 hrs. 12:00 18:00 6.00 16,212 16,872 PROD1 DRILL DDRL P DrIg from 16212'MD to 16872'MD, TVD=6240', ART=4.21,ADT=4.21. Total jar hrs= 152.07 Bit hrs=31.11 PU wt= 175k, SO wt=66k, ROT wt = 110k. TQ on = 13k, TQ off=10k. ECD= 12.91. Flow out=40%,WOB =5-10k, RPM = 140, GPM =237, SPP=3100 Obtain SPR's @ 16500'MD TVD= 6232', MW 10.9 ppg 13:30 hours MP#1=20 spm=800 psi, 30 spm= 1180psi. MP#2: 20 spm=790 psi, 30 spm= 1100 psi. 18:00 00:00 6.00 16,872 17,489 PROD1 DRILL DDRL P DrIg from 16872'MD to 17489' MD, TVD=6251', ART=3.98,ADT=3.98. Total jar hrs= 156.05 Bit hrs=35.09 PU wt= 180k, SO wt=58k, ROT wt = 111k. TQ on = 14k, TO off=11k. ECD= 12.8. Flow out=38%,WOB =5-10k, RPM = 140, GPM =236, SPP=3075 Kick w/Drilling CRT= 120 sec @ 20:45 hrs. Page 23 of 29 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/17/2014 24 hr Summary Directional drilled production section from 17489'to TD @ 18670'MD, 6265 TVD. CBU 3X racking back a stand every BU. Monitor well till static. BROOH 18484'-16404' MD. 00:00 06:00 6.00 17,489 18,197 PROD1 DRILL DDRL P DrIg from 17489' MD to 18197' MD, TVD=6262', ART=4.48,ADT=4.48. Total jar hrs= 160.53 Bit hrs=39.57 PU wt= 192k, SO wt=Ok, ROT wt = 110k. TQ on= 14k,TQ off=13k. ECD= 12.87. Flow out=41%,WOB =5-10k, RPM = 140, GPM=237, SPP=3200 06:00 11:30 5.50 18,197 18,670 PROD1 DRILL DDRL P Drlg from 18197'MD to 18670'MD, TVD=6265', ART=3.41,ADT=3.41. Total jar hrs= 163.94 Bit hrs=42.98 PU wt= 195k, SO wt=0k, ROT wt = 111k. TQ on= 14k, TQ off=12k. ECD= 13. Flow out=39%,WOB= 4-7k, RPM= 140, GPM =240, SPP =3290 SPR's @ 18670' MD TVD=6265', MW 10.9 ppg 11:30 hours MP#1= 20 spm=900 psi, 30 spm= 1230psi. MP#2: 20 spm=870 psi, 30 spm= 1240 psi. 11:30 12:00 0.50 18,670 18,670 PROD1 CASING SRVY P Check shot survey at TD 18670'MD. 12:00 17:00 5.00 18,670 18,484 PROD1 CASING CIRC P CBU 3X from 18670'-18484' MD, 235 gpm, 3100 psi, 100 rpm, 11K TQ, 17:00 18:45 1.75 18,484 18,484 PROD1 CASING OWFF P Monitor well, slight flow decreasing ,to static. 18:45 22:30 3.75 18,484 16,686 PROD1 CASING REAM P BROOH from 18484'-16686' MD, 220 gpm, 2700 psi, 100 rpm, 12k TQ, FO 38%. Pit gain noted on trip sheet. Decide to monitor well. 22:30 22:45 0.25 16,686 16,686 PROD1 CASING OWFF P Monitor well, observe flow decreasing to slight flow. 22:45 23:30 0.75 16,686 16,686 PROD1 CASING CIRC P Circulate&condition, recheck trip sheet& PVT's to re-verify no gain taken during trip. 23:30 00:00 0.50 16,686 16,404 PROD1 CASING REAM P BROOH from 16686'-16404' MD, PU 110k, 220 gpm,2550 psi, 100 rpm, 10.5k TQ, FO 38%. Calculated fill 10.8, actual 23.84 bbls. 09/18/2014 BROOH f/16404'-12521' MD. CBU&increase MW to 11.0 ppg. Pump out of hole from 12521'-3066'MD. TOH to BHA on elevators. Begin L/D BHA to NMFC. 00:00 07:00 7.00 16,404 12,521 PROD1 CASING REAM P BROOH from 16404'-12521' MD, 220 gpm, 2500 psi, FO 38%, 100 rpm, 10.5k TQ, 1000-1500 fph. Calculated fill 23.22, actual 51 bbls. Page24of29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:15 1.25 12,521 12,521 PROD1 CASING CIRC P CBU @ 240 gpm, 2880 psi,40%FO, 40 rpm, 8k TQ, PU 172k, SO 77k, ROT 113k. Increase MW to 11.0 pp9• SPR's @ 12521'MD TVD=6165', MW 11.0 ppg 08:00 hrs MP#1=20 spm=690 psi, 30 spm= 1060psi. MP#2:20 spm=690 psi, 30 spm= 1070 psi. Kick w/Tripping Drill CRT=39 sec @ 08:00 hrs. 08:15 09:00 0.75 12,521 12,521 PROD1 CASING OWFF P Monitor well, slight flow to static, Drop 1.6"hollow body drift in DP. 09:00 20:30 11.50 12,521 3,066 PROD1 CASING TRIP P Pump out of hole from 12521'-3066' MD, 3 bpm, 950 psi, FO 30%, PU 70k, SO 60k. Calcualted fill 64.8, actual 86.1 bbls. 20:30 21:00 0.50 3,066 3,066 PROD1 CASING OWFF P Monitor well, static. Blow down TD. 21:00 22:45 1.75 3,066 414 PROD1 CASING TRIP P POOH from 3066'-414'MD. Calculated fill 15.1, actual 18.36 bbls. 22:45 23:00 0.25 414 414 PROD1 CASING OWFF P Monitor well, static. SIM-OP PJSM for BHA&nuke source handling. 23:00 00:00 1.00 414 125 PROD1 CASING PULD P Lay down BHA as per SLB, 2 HWDP,Jars,Well Commander, 3 NMFC, remove nuke sources. 09/19/2014 Finish L/D BHA#4. Clear rig floor. Rig up&run 4.5"production liner as per detail to 6281' MD. Make up liner hanger as per Baker Rep. Circulate liner volume.RIH on DP f/6281'-12422' MD. Stage up pump to CBU. Continue RIH on DP to 13729' MD. 00:00 01:30 1.50 125 0 PROD1 CASING PULD P Lay down BHA 4 as per SLB DD. 01:30 02:00 0.50 0 0 PROD1 CASING RURD P Clear&clean rig floor. 02:00 02:30 0.50 0 0 COMPZ CASING WWWH P Flush stack with stack washer. 02:30 04:00 1.50 0 0 COMPZ CASING RURD P Rig up casing equipment to run liner. 04:00 04:45 0.75 0 0 COMPZ CASING RURD P Finish lining up jewelry in pipe shed to match running order. 04:45 11:00 6.25 0 6,281 COMPZ CASING PUTB P PJSM&RIH w/4.5", 12.6#, L80, Hydril 563, R3 liner from surface to 6281'MD as per detail. Calculated displacement 28.93, actual 28 bbls. 11:00 12:00 1.00 6,281 6,281 COMPZ CASING PULD P Pick up liner hanger&make up as per Baker Rep. Spill Drill CRT= 175 sec @ 11:00 hrs. 12:00 13:00 1.00 6,281 6,281 COMPZ CASING CIRC P Circulate liner volume @ 2 bpm, 380 psi, 13%FO, PU 85K, SO 60K. 13:00 20:00 7.00 6,281 12,422 COMPZ CASING RUNL P RIH with 4.5"liner on drill pipe from 6281'- 12422' MD, PU 142k, SO 82k. 20:00 23:00 3.00 12,422 12,422 COMPZ CASING CIRC P CBU staging up pumps from .5-3 bpm=350-775 psi. Attain parameters before going into open hole PU 142K, SO 82K, ROT 106K,20&30 rpm, TQ 7-8k. Page 25 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 12,422 13,729 COMPZ CASING RUNL P RIH with 4.5"liner on drill pipe from 12422'- 13729' MD, PU 152k, SO 75k. 09/20/2014 Continue RIH to TD @ 18760' MD. Circulate a string volume&shift close TCS. Hang of liner&set packer @ 18650' MD, liner top @ 12368'MD. PT entire system to 3500 psi. Displace to seawater. Observed slight flow decreasing, but would not go static, SIMOPS slip&cut drill line. CBU. Monitor well,observed for 30 min static.TOH laying down 4" DP f/12272'-11069' MD. 00:00 06:00 6.00 13,729 18,650 COMPZ CASING RUNL P Cont to RIH w/4-1/2"liner on 4" DP f/13729'MD,tag bottom @ 18670 w/ 3K. P/U to setting depth @ 18650' MD. P/U=210K, S/O=75K.Actual displacement=25.5 bbls, Calculated displacement=29.7 bbls. 06:00 08:00 2.00 18,650 18,650 COMPZ CASING CIRC P Circulate pipe volume, stage pumps up from 1/2 bpm to 3 bpm= 1580 psi, 28%flow. 08:00 12:00 4.00 18,650 12,272 COMPZ CASING HOSO P Drop 1.25"to close TCS&pump down @ 3 bpm, 1500 psi, FO 31%. Slow down to 1 bpm,650 psi& observe ball set w/2450 strokes. Pressure up to 1500 psi, hold 10min. Bleed down to 500 psi&pressure up to 1500 psi.Attempt to hydraulic release several times. Confer w/ Baker adviser&decide to use left hand release method.Apply 7 left hand turns in string,working torque down w/each turn. Slack off, let out torque, &set 50k on string. Pick up &observe liner weight gone. Set 50k down weight&rotate w/torque set at 5k, stalling out.This indicated release. Set ZXP&release. Pick up 10'to clear the rotating dog sub as per Baker Rep. Liner shoe set at 18650'MD, Liner top set at 12368' MD. PU 165k, SO 85k. 12:00 12:30 0.50 12,272 12,272 COMPZ CASING RURD P Rig up test equipment. 12:30 13:00 0.50 12,272 12,272 COMPZ CASING PRTS P Pressure test 4.5"liner, liner top, &7 5/8"casing to 3500 psi for 15 min, charted. 13:00 13:30 0.50 12,272 12,272 COMPZ CASING OWFF P Monitor well,static. 13:30 14:00 0.50 12,272 12,272 COMPZ CASING RURD P Rig down test equipment. 14:00 17:30 3.50 12,272 12,272 COMPZ CASING DISP P Displace well to 8.5 brine,then 2 BU to clean up.Total brine pumped 1453,total returns 1453 bbls. 17:30 19:00 1.50 12,272 12,272 COMPZ CASING OWFF P Monitor well, observe slight flow. 19:00 20:30 1.50 12,272 12,272 COMPZ CASING SLPC P Slip&cut 124'of drilling line. SIMOP OWFF, perform vis-cup test to establish flow rate. 20:30 21:30 1.00 12,272 12,272 COMPZ CASING OWFF P Monitor well, observe flow slowing to slight ooze without stopping. 21:30 22:30 1.00 12,272 12,272 COMPZ CASING CIRC P CBU @ 8 bpm, 1350 psi, no gain or loss. Page 26 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 12,272 12,272 COMPZ CASING OWFF P Monitor well, no flow observed, static. 23:00 00:00 1.00 12,272 11,069 COMPZ CASING PULD P Lay down drill pipe from 12272'-11069' MD. 09/21/2014 Finished TOH laying down 4"DP. L/D liner running tool. Remove wear bushing. Perform dummy run with hanger. Test liner top to 3500 psi for 30 min. Rig up to run upper completion. Run 3.5"upper completion as per detail,from surface to 7806'MD. 00:00 08:15 8.25 11,069 50 COMPZ CASING PULD P PJSM, Cont POOH L/D 4"drill pipe f/ 11069' MD to 50'MD.Actual displacement=78.71 bbls, Calculated displacement=73.16 bbls. 08:15 08:30 0.25 50 0 COMPZ CASING PULD P L/D running tool as per Baker rep. Dog sub was sheared and confirmed left hand release of liner. 08:30 08:45 0.25 0 0 COMPZ RPCOM RURD P Clean and clear rig floor.. 08:45 09:15 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 09:15 09:45 0.50 0 0 COMPZ RPCOM OTHR P M/U tbg hanger to landing joint as per CIW rep. Perform dummy run and mark landing joint. 09:45 10:45 1.00 0 0 COMPZ RPCOM PRTS P R/U and test liner top packer to 3500 psi for 30 minutes on chart, good test. 10:45 12:45 2.00 0 0 COMPZ RPCOM RURD P Rig tubing handling equipment, SLB equipment, I-wire, &cannon clamps. 12:45 14:00 1.25 0 926 COMPZ RPCOM PUTB P PJSM, run 3.5", L-80, 8RD Mod, tubing completion as per detail. From surface to 926'MD. 14:00 14:30 0.50 926 926 COMPZ RPCOM PUTB P Make up&install I-wire to gauge carrier. 14:30 00:00 9.50 926 7,806 COMPZ RPCOM PUTB P Continue running 3.5", L-80, 8RD Mod, tubing completion as per detail. From 926'-7806' MD. Test I-wire connectivity every 30 jts. Used 9 half clamps&221 full clamps to depth. Calculated displacement 23.4, actual 24.8 bbls 09/22/2014 Continue tubing run to liner top. Space out&make up hanger w/landing joint. Spot inhibited sea water. Land hanger&RILDS. Packer set at 11492'MD. PT 3.5"tubing&IA to 3500 psi for 30 min. Shear out DCK-1 valve. Install BPV&test. N/D BOPE. N/U adapter&tree. Hanger seals,void,&tree tested to 5000 psi. Freeze protect well w/95 bbls diesel&line up to u-tube. 00:00 06:15 6.25 7,806 12,378 COMPZ RPCOM PUTB P Continue running 3.5", L-80, 8RD Mod,tubing completion as per detail. From 7806'-12378' MD. Test I-wire connectivity every 30 jts. Used 12 half clamps&371 full clamps, 1 full 4.5"clamp, &2 half 4.5"clamps. PU 110k, SO 64k. Calculated displacement 20.74, actual 19.33 bbls. 06:15 07:30 1.25 12,378 12,348 COMPZ RPCOM HOSO P Space out laying down 3 jts of 3.5" tubing, P/U 10.29',4.18',2.35'-3.5" tubing pups;XO; 1 jt of 4.5"tubing. Page 27 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 12,348 12,361 COMPZ RPCOM THGR P Make up hanger&circulating equipment. Stage up pumps to 3.5 bpm,400 psi. Slack off&observe psi increase to 420 psi, indicating WLEG entering tie back sleave. 08:00 09:00 1.00 12,361 12,361 COMPZ RPCOM THGR P Terminate I-wire under hanger as per SLB&Cameron Rep's. 09:00 10:00 1.00 12,361 12,361 COMPZ RPCOM CRIH P Pump 128 bbls of 2%CRW 8.5ppg seawater, chased with 106 bbls of 8,.5ppg seawater©4 bpm, 600 psi, FO 27%. Fire Drill CRT= 136 sec @ 09:00 hrs 10:00 10:45 0.75 12,361 12,391 COMPZ RPCOM THGR P Drain stack, land tubing hanger, RILDS. 10:45 11:00 0.25 12,391 12,391 COMPZ RPCOM PRTS P Test hanger seals to 5000 psi for 10 min. Good. 11:00 11:45 0.75 12,391 12,391 COMPZ RPCOM PACK P Drop 1.3125"ball&rod, let fall 15 min. Pressure up to 2000 psi for 5 min, continue to psi up to 3500 psi to set the packer. Packer set at 11492.67'MD. 11:45 13:15 1.50 12,391 12,391 COMPZ RPCOM PRTS P Test tubing for 30 min @ 3500 psi. Bleed tubing to 2500 psi&pressure test IA to 3500 psi for 30 min. Bleed of tubing to shear SOV.All tests charted. 13:15 14:00 0.75 12,391 12,391 COMPZ RPCOM OWFF P Monitor well, flow decreasing then 30 min. static. 14:00 14:15 0.25 12,391 12,391 COMPZ WHDBO MPSP P Set BPV&test 250/2500 psi, 5 min each on chart. 14:15 14:30 0.25 12,391 12,391 COMPZ WHDBO OWFF P Monitor well, static. 14:30 15:30 1.00 12,391 0 COMPZ WHDBO NUND P Blow down lines&nipple down BOPE. 15:30 16:15 0.75 0 0 COMPZ WHDBO NUND P Set test dart&coordinate with DSO on orientation of tree adapter. 16:15 18:45 2.50 0 0 COMPZ WHDBO NUND P Nipple up tree adapter.Attempt to test SRL seals , dart leaking. Troubleshoot dart. 18:45 19:15 0.50 0 0 COMPZ WHDBO NUND P Finish terminating I-wire as per SLB. 19:15 19:45 0.50 0 0 COMPZ WHDBO PRTS P Pressure test void to 5000 psi for 10 min. Co-man verified good. 19:45 20:30 0.75 0 0 COMPZ WHDBO NUND P Nipple up tree&line to freeze protect. 20:30 21:00 0.50 0 0 COMPZ WHDBO MPSP P Pull dart&BPV. Install 2-way check. 21:00 22:00 1.00 0 0 COMPZ WHDBO PRTS P R/U test equipment&PT tree to 5000 psi for 5 min on chart. 22:00 22:30 0.50 0 0 COMPZ WHDBO MPSP P Pull 2-way check. 22:30 00:00 1.50 0 0 COMPZ WHDBO FRZP P R/U&PT lines to 2500 psi. Pump 95 bbls diesel down the IA,taking returns from the tubing. ICP 2 bpm= 800 psi, FCP 2 bpm= 1150 psi. Shut in w/1150 psi on IA. Line up& U-tube well. Page 28 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/23/2014 24 hr Summary Lay down remaining drill pipe. Secure well. Clean&prepare rig for move. Disconnected from highline @ 15:30 hrs. Rig release @ 24:00 hrs. 00:00 01:00 1.00 0 0 COMPZ WHDBO FRZP P U-tube diesel freeze protect. Sim-ops blow down&rig down lines in cellar. R/U to lay down 4" DP. 01:00 01:30 0.50 0 0 COMPZ WHDBO SVRG P Service rig. Man Down Drill Table Top Review. 01:30 05:30 4.00 0 0 COMPZ WHDBO FRZP P Continue U-tube of diesel freeze protect. Lay down remaining 4"DP from derrick. 05:30 07:30 2.00 0 0 COMPZ WHDBO MPSP P Rig up&PT lubricator. Set BPV as per Cameron Rep. Secure well, IA 0 psi, SITP 0 psi. 07:30 12:00 4.50 0 0 DEMOB MOVE RURD P Remove kelly hose&clean TD. Remove bales from TD. Clean air slips. Clean pits&rock washer. 12:00 00:00 12.00 0 0 DEMOB MOVE RURD P Continue to clean pits, top drive. Remove IR track&rotary table cover. Clean rotary table&drip pans under rig floor. Clean under skate rails. Prep choke manifold for removal. Disconnect high line @ 15:30 hrs. Spill Drill CRT=88 sec© 19:45 hrs. Page 29 of 29 l 0 • NADConversion Kuparuk River Unit Kuparuk 2E Pad 2E-01 Definitive Survey Report [NAD 2 7 26 September, 2014 0 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 III Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2E-01 Well Position i-N/-S 0.00 usft Northing: 5,944,147.20 usft Latitude: 70°15'30.495 N +E/-W 0.00 usft Easting: 529,971.92 usft Longitude: 149°45'27.903 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 105.10 usft Wellbore 2E-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (0) (nT) BGGM2014 9/15/2014 19.20 80.87 57,574 Design 2E-01 ,i..vii ii ii n;dliiv4i1E1 uuisi 11,11iiiiiiiimi11IIII Milli In a,w. ,., Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.20 Vertical Section: - Depth From(TVD) +N/-S +E/-W Direction 40i w „i lig illill (usft) (usft) (usft) (°) , 27.20 0.00 0.00 180.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 82.30 912.27 2E-01 Svy1 NSG+MSHOT(2E-01) GYD-GC-MS Gyrodata gyrocompassing m/s 9/25/2014 4:39: 968.94 18,590.61 2E-01 Svy2 MWD+GMAG(2E-01) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/25/2014 4:56: 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) (0/100') (ft) Survey Tool Name 27.20 0.00 0.00 27.20 -105.10 0.00 0.00 5,944,147.20 529,971.92 0.00 0.00 UNDEFINED 82.30 0.12 346.37 82.30 -50.00 0.06 -0.01 5,944,147.26 529,971.91 0.22 -0.06 GYD-GC-MS(1) 106.60 0.13 355.95 106.60 -25.70 0.11 -0.02 5,944,147.31 529,971.90 0.10 16"x 42" 169.97 0.17 13.79 169.97 37.67 0.27 0.00 5,944,147.47 529,971.92 0.10 -0.27 GYD-GC-MS(1) 267.63 0.29 17.67 267.63 135.33 0.65 0.11 5,944,147.85 529,972.02 0.12 -0.65 GYD-GC-MS(1) 360.76 1.24 230.29 360.75 228.45 0.23 -0.60 5,944,147.43 529,971.32 1.60 -0.23 GYD-GC-MS(1) 452.70 1.88 226.15 452.66 320.36 -1.45 -2.45 5,944,145.74 529,969.48 0.71 1.45 GYD-GC-MS(1) 544.39 2.83 225.41 544.27 411.97 -4.08 -5.15 5,944,143.10 529,966.79 1.04 4.08 GYD-GC-MS(1) 637.42 5.44 223.67 637.05 504.75 -8.89 -9.83 5,944,138.28 529,962.13 2.81 8.89 GYD-GC-MS(1) 729.79 7.68 229.83 728.81 596.51 -16.04 -17.57 5,944,131.10 529,954.42 2.54 16.04 GYD-GC-MS(1) 819.52 9.86 231.62 817.49 685.19 -24.67 -28.18 5,944,122.42 529,943.85 2.45 24.67 GYD-GC-MS(1) 912.27 12.11 231.93 908.53 776.23 -35.60 -42.06 5,944,111.43 529,930.01 2.43 35.60 GYD-GC-MS(1) 9/26/2014 9:45::40AM Page 2 COMPASS 5000.1 Build 65 ` • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 968.94 12.65 232.03 963.88 831.58 -43.09 -51.63 5,944,103.91 529,920.47 0.95 43.09 MWD+IFR-AK-CAZ-SC(2) 1,061.15 13.77 231.80 1,053.65 921.35 -56.09 -68.22 5,944,090.85 529,903.94 1.22 56.09 MWD+IFR-AK-CAZ-SC(2) 1,155.70 16.06 231.53 1,145.01 1,012.71 -71.18 -87.30 5,944,075.68 529,884.91 2.42 71.18 MWD+IFR-AK-CAZ-SC(2) 1,245.72 17.37 231.58 1,231.22 1,098.92 -87.28 -107.58 5,944,059.50 529,864.70 1.46 87.28 MVVD+IFR-AK-CAZ-SC(2) 1,339.70 19.81 230.13 1,320.29 1,187.99 -106.21 -130.80 5,944,040.48 529,841.56 2.64 106.21 MWD+IFR-AK-CAZ-SC(2) 1,432.92 21.09 230.37 1,407.64 1,275.34 -127.03 -155.84 5,944,019.56 529,816.61 1.38 127.03 MWD+IFR-AK-CAZ-SC(2) 1,524.42 21.03 230.51 1,493.03 1,360.73 -147.98 -181.19 5,943,998.52 529,791.34 0.09 147.98 MWD+IFR-AK-CAZ-SC(2) 1,617.89 24.73 229.09 1,579.13 1,446.83 -171.45 -208.92 5,943,974.93 529,763.71 4.00 171.45 MWD+IFR-AK-CAZ-SC(2) 1,710.50 27.43 228.92 1,662.30 1,530.00 -198.16 -239.64 5,943,948.11 529,733.09 2.92 198.16 MWD+IFR-AK-CAZ-SC(2) 1,803.00 29.65 228.87 1,743.55 1,611.25 -227.21 -272.94 5,943,918.92 529,699.92 2.40 227.21 MWD+IFR-AK-CAZ-SC(2) 1,895.81 33.32 229.39 1,822.69 1,690.39 -258.92 -309.59 5,943,887.08 529,663.39 3.97 258.92 MWD+IFR-AK-CAZ-SC(2) 1,988.11 36.46 231.39 1,898.39 1,766.09 -292.54 -350.28 5,943,853.30 529,622.84 3.62 292.54 MWD+IFR-AK-CAZ-SC(2) 2,081.00 40.84 233.55 1,970.92 1,838.62 -327.83 -396.30 5,943,817.83 529,576.96 4.93 327.83 MWD+IFR-AK-CAZ-SC(2) 2,172.88 43.86 233.38 2,038.82 1,906.52 -364.67 -446.03 5,943,780.79 529,527.39 3.29 364.67 MWD+IFR-AK-CAZ-SC(2) 2,266.07 48.03 233.43 2,103.60 1,971.30 -404.59 -499.79 5,943,740.66 529,473.80 4.47 404.59 MVVD+IFR-AK-CAZ-SC(2) 2,358.72 51.49 233.04 2,163.44 2,031.14 -446.92 -556.43 5,943,698.11 529,417.33 3.75 446.92 MWD+IFR-AK-CAZ-SC(2) 2,451.27 53.55 232.27 2,219.76 2,087.46 -491.47 -614.81 5,943,653.33 529,359.13 2.32 491.47 MVVD+IFR-AK-CAZ-SC(2) 2,542.00 56.53 231.27 2,271.74 2,139.44 -537.49 -673.21 5,943,607.09 529,300.92 3.41 537.49 MWD+IFR-AK-CAZ-SC(2) 2,634.73 59.15 231.16 2,321.09 2,188.79 -586.66 -734.40 5,943,557.68 529,239.94 2.83 586.66 MWD+IFR-AK-CAZ-SC(2) 2,727.57 62.83 230.94 2,366.11 2,233.81 -637.70 -797.53 5,943,506.40 529,177.02 3.97 637.70 MWD+IFR-AK-CAZ-SC(2) 2,819.76 64.69 231.70 2,406.87 2,274.57 -689.37 -862.08 5,943,454.47 529,112.68 2.15 689.37 MWD+IFR-AK-CAZ-SC(2) 2,913.00 64.99 229.96 2,446.51 2,314.21 -742.67 -927.50 5,943,400.92 529,047.48 1.72 742.67 MWD+IFR-AK-CAZ-SC(2) 3,005.29 65.43 228.99 2,485.21 2,352.91 -797.11 -991.19 5,943,346.23 528,984.01 1.07 797.11 MWD+IFR-AK-CAZ-SC(2) 3,095.53 66.12 228.56 2,522.24 2,389.94 -851.35 -1,053.08 5,943,291.75 528,922.34 0.88 851.35 MWD+IFR-AK-CAZ-SC(2) 3,189.54 67.82 228.01 2,559.01 2,426.71 -908.92 -1,117.66 5,943,233.93 528,858.00 1.89 908.92 MVVD+IFR-AK-CAZ-SC(2) 3,281.46 67.82 228.08 2,593.72 2,461.42 -965.82 -1,180.96 5,943,176.78 528,794.93 0.07 965.82 MVVD+IFR-AK-CAZ-SC(2) 3,375.75 66.78 227.25 2,630.10 2,497.80 -1,024.40 -1,245.26 5,943,117.95 528,730.87 1.37 1,024.40 MWD+IFR-AK-CAZ-SC(2) 3,468.55 65.99 227.20 2,667.28 2,534.98 -1,082.15 -1,307.67 5,943,059.97 528,668.70 0.85 1,082.15 MWD+IFR-AK-CAZ-SC(2) 3,561.77 66.45 228.87 2,704.87 2,572.57 -1,139.18 -1,371.10 5,943,002.68 528,605.50 1.71 1,139.18 MWD+IFR-AK-CAZ-SC(2) 3,654.01 68.08 230.77 2,740.52 2,608.22 -1,194.06 -1,436.10 5,942,947.55 528,540.73 2.59 1,194.06 MWD+IFR-AK-CAZ-SC(2) 3,746.83 66.20 232.25 2,776.58 2,644.28 -1,247.29 -1,503.03 5,942,894.06 528,474.01 2.50 1,247.29 MWD+IFR-AK-CAZ-SC(2) 3,839.66 65.45 232.86 2,814.59 2,682.29 -1,298.79 -1,570.27 5,942,842.31 528,406.99 1.01 1,298.79 MWD+IFR-AK-CAZ-SC(2) 3,931.94 68.89 233.36 2,850.39 2,718.09 -1,349.83 -1,638.28 5,942,791.00 528,339.19 3.76 1,349.83 MWD+IFR-AK-CAZ-SC(2) 4,024.19 68.08 234.02 2,884.22 2,751.92 -1,400.65 -1,707.44 5,942,739.91 528,270.24 1.10 1,400.65 MWD+IFR-AK-CAZ-SC(2) 4,116.12 67.82 233.43 2,918.74 2,786.44 -1,451.06 -1,776.13 5,942,689.23 528,201.76 0.66 1,451.06 MWD+IFR-AK-CAZ-SC(2) 4,209.22 66.78 233.27 2,954.66 2,822.36 -1,502.33 -1,845.04 5,942,637.69 528,133.06 1.13 1,502.33 MWD+IFR-AK-CAZ-SC(2) 4,301.85 66.16 233.23 2,991.64 2,859.34 -1,553.14 -1,913.09 5,942,586.61 528,065.22 0.67 1,553.14 MWD+IFR-AK-CAZ-SC(2) 4,392.57 65.78 232.98 3,028.59 2,896.29 -1,602.89 -1,979.35 5,942,536.61 527,999.16 0.49 1,602.89 MWD+IFR-AK-CAZ-SC(2) 4,485.66 65.97 233.60 3,066.64 2,934.34 -1,653.67 -2,047.46 5,942,485.56 527,931.26 0.64 1,653.67 MWD+IFR-AK-CAZ-SC(2) 4,579.61 65.84 232.96 3,104.99 2,972.69 -1,704.95 -2,116.20 5,942,434.01 527,862.73 0.64 1,704.95 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45::40AM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,672.32 65.63 231.92 3,143 09 3,010.79 -1,756.47 -2,183.20 5,942,382.23 527,795.94 1.05 1,756.47 MWD+IFR-AK-CAZ-SC(2) 4,765.03 64.96 230.67 3,181.84 3,049.54 -1,809.13 -2,248.93 5,942,329.31 527,730.43 1.42 1,809.13 MWD+IFR-AK-CAZSC(2) 4,855.65 65.16 230.17 3,220.05 3,087.75 -1,861.49 -2,312.26 5,942,276.71 527,667.32 0.55 1,861.49 MWD+IFR-AK-CAZSC(2) 4,869.57 65.11 230.15 3,225.91 3,093.61 -1,869.58 -2,321.96 5,942,268.58 527,657.65 0.38 1,869.58 MWD+IFR-AK-CAZ-SC(2) 4,939.70 65.67 230.50 3,255.11 3,122.81 -1,910.28 -2,371.03 5,942,227.69 527,608.74 0.92 1,910.28 10-314"x13-112' 1 4,959.62 65.83 230.60 3,263.29 3,130.99 -1,921.82 -2,385.06 5,942,216.09 527,594.77 0.92 1,921 82 MWD+IFR-AK-CAZ-SC(2) 5,052.34 67.44 230.66 3,300.06 3,167.76 -1,975.81 -2,450.86 5,942,161.85 527,529.19 1.74 1,975.81 MWD+IFR-AK-CAZ-SC(2) 5,146.51 67.94 231.04 3,335.81 3,203.51 -2,030.82 -2,518.42 5,942,106.58 527,461.85 0.65 2,030.82 MWD+IFR-AK-CAZ-SC(2) 5,238.93 67.62 231.91 3,370.76 3,238.46 -2,084.11 -2,585.35 5,942,053.03 527,395.14 0.94 2,084.11 MWD+IFR-AK-CAZ-SC(2) 5,330.93 66.42 229.85 3,406.68 3,274.38 -2,137.54 -2,651.06 5,941,999.34 527,329.65 2.44 2,137.54 MWD+IFR-AK-CAZ-SC(2) 5,421.69 64.94 227.42 3,444.06 3,311.76 -2,192.18 -2,713.13 5,941,944.46 527,267.80 2.93 2,192.18 MWD+IFR-AK-CAZ-SC(2) 5,514.43 64.90 227.06 3,483.37 3,351.07 -2,249.21 -2,774.80 5,941,887.19 527,206.37 0.35 2,249.21 MWD+IFR-AK-CAZ-SC(2) 5,608.06 64.79 227.96 3,523.17 3,390.87 -2,306.45 -2,837.30 5,941,829.71 527,144.11 0.88 2,306.45 MWD+IFR-AK-CAZ-SC(2) 5,699.60 64.79 229.93 3,562.17 3,429.87 -2,360.84 -2,899.74 5,941,775.07 527,081.88 1.95 2,360.84 MWD+IFR-AK-CAZ-SC(2) 5,793.29 64.76 232.01 3,602.10 3,469.80 -2,414.21 -2,965.58 5,941,721.45 527,016.27 2.01 2,414.21 MVVD+IFR-AK-CAZ-SC(2) 5,884.77 64.80 233.84 3,641.08 3,508.78 -2,464.10 -3,031.61 5,941,671.30 526,950.45 1.81 2,464.10 MWD+IFR-AK-CAZSC(2) 5,977.75 64.57 234.42 3,680.84 3,548.54 -2,513.35 -3,099.72 5,941,621.78 526,882.54 0.62 2,513.35 MWD+IFR-AK-CAZ-SC(2) 6,071.02 64.78 234.34 3,720.73 3,588.43 -2,562.45 -3,168.25 5,941,572.42 526,814.21 0.24 2,562.45 MWD+IFR-AK-CAZ-SC(2) 6,163.31 64.64 234.53 3,760.16 3,627.86 -2,610.99 -3,236.13 5,941,523.62 526,746.53 0.24 2,610.99 MWD+IFR-AK-CAZ-SC(2) 6,255.40 64.64 234.58 3,799.60 3,667.30 -2,659.24 -3,303.92 5,941,475.09 526,678.94 0.05 2,659.24 MWD+IFR-AK-CAZ-SC(2) 6,348.83 64.62 235.10 3,839.64 3,707.34 -2,707.86 -3,372.94 5,941,426.21 526,610.12 0.50 2,707.86 MWD+IFR-AK-CAZ-SC(2) 6,441.54 64.62 235.56 3,879.37 3,747.07 -2,755.51 -3,441.83 5,941,378.29 526,541.43 0.45 2,755.51 MWD+IFR-AK-CAZ-SC(2) 6,534.39 64.62 235.71 3,919.17 3,786.87 -2,802.86 -3,511.07 5,941,330.67 526,472.38 0.15 2,802.86 MWD+IFR-AK-CAZ-SC(2) 6,627.16 64.68 235.79 3,958.89 3,826.59 -2,850.04 -3,580.37 5,941,283.22 526,403.27 0.10 2,850.04 MWD+IFR-AK-CAZ-SC(2) 6,720.81 64.64 235.11 3,998.97 3,866.67 -2,898.04 -3,650.08 5,941,234.94 526,333.76 0.66 2,898.04 MWD+IFR-AK-CAZ-SC(2) 6,811.76 64.65 234.17 4,037.92 3,905.62 -2,945.61 -3,717.11 5,941,187.12 526,266.93 0.93 2,945.61 MWD+IFR-AK-CAZSC(2) 6,904.52 64.64 233.55 4,077.64 3,945.34 -2,995.04 -3,784.80 5,941,137.42 526,199.44 0.60 2,995.04 MWD+IFR-AK-CAZSC(2) 6,997.88 64.62 232.06 4,117.64 3,985.34 -3,046.04 -3,852.00 5,941,086.16 526,132.46 1.44 3,046.04 MWD+IFR-AK-CAZ-SC(2) 7,090.24 64.26. 230.46 4,157.50 4,025.20 -3,098.17 -3,916.99 5,941,033.77 526,067.68 1.61 3,098.17 MWD+IFR-AK-CAZ-SC(2) 7,183.95 64.13 229.60 4,198.29 4,065.99 -3,152.37 -3,981.64 5,940,979.33 526,003.25 0.84 3,152.37 MWD+IFR-AK-CAZ-SC(2) 7,274.33 64.37 228.72 4,237.55 4,105.25 -3,205.60 -4,043.23 5,940,925.85 525,941.88 0.92 3,205.60 MWD+IFR-AK-CAZ-SC(2) 7,367.45 64.55 228.62 4,277.70 4,145.40 -3,261.09 -4,106.32 5,940,870.12 525,879.02 0.22 3,261.09 MWD+IFR-AK-CAZ-SC(2) 7,462.22 64.66 229.02 4,318.35 4,186.05 -3,317.46 -4,170.75 5,940,813.50 525,814.81 0.40 3,317.46 MWD+IFR-AK-CAZ-SC(2) 7,554.35 64.96 229.48 4,357.56 4,225.26 -3,371.88 -4,233.91 5,940,758.84 525,751.88 0.56 3,371.88 MWD+IFR-AK-CAZ-SC(2) 7,647.05 65.19 229.89 4,396.62 4,264.32 -3,426.27 -4,298.01 5,940,704.20 525,688.00 0.47 3,426.27 MWD+IFR-AK-CAZ-SC(2) 7,737.49 65.12 231.03 4,434.63 4,302.33 -3,478.51 -4,361.30 5,940,651.71 525,624.93 1.15 3,478.51 MWD+IFR-AK-CAZ-SC(2) 7,828.15 65.18 232.01 4,472.73 4,340.43 -3,529.70 -4,425.70 5,940,600.27 525,560.74 0.98 3,529.70 MWD+IFR-AK-CAZSC(2) 7,922.94 65.08 232.71 4,512.59 4,380.29 -3,582.22 -4,493.80 5,940,547.48 525,492.86 0.68 3,582.22 M1.ND+IFR-AK-CAZSC(2) 8,015.71 65.01 232.96 4,551.73 4,419.43 -3,633.03 -4,560.83 5,940,496.41 525,426.04 0.26 3,633.03 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,108.53 65.15 233.64 4,590.84 4,458.54 -3,683.34 -4,628.32 5,940,445.84 525,358.76 0.68 3,683.34 MWD+IFR-AK-CAZ-SC(2) 8,201.55 65.09 233.68 4,629.98 4,497.68 -3,733.34 -4,696.29 5,940,395.57 525,290.99 0.08 3,733.34 MWD+IFR-AK-CAZ-SC(2) 8,295.16 65.05 233.36 4,669.43 4,537.13 -3,783.81 -4,764.55 5,940,344.83 525,222.94 0.31 3,783.81 MWD+IFR-AK-CAZ-SC(2) 8,386.86 65.06 233.51 4,708.11 4,575.81 -3,833.34 -4,831.33 5,940,295.04 525,156.36 0.15 3,833.34 MWD+IFR-AK-CAZ-SC(2) 8,480.44 65.12 233.74 4,747.52 4,615.22 -3,883.68 -4,899.66 5,940,244.44 525,088.24 0.23 3,883.68 MWD+IFR-AK-CAZ-SC(2) 8,572.33 65.22 233.50 4,786.11 4,653.81 -3,933.15 -4,966.81 5,940,194.71 525,021.30 0.26 3,933.15 MWD+IFR-AK-CAZ-SC(2) 8,666.54 65.16 233.50 4,825.64 4,693.34 -3,984.01 -5,035.55 5,940,143.58 524,952.77 0.06 3,984.01 MVVD+IFR-AK-CAZ-SC(2) 8,755.96 65.15 232.81 4,863.21 4,730.91 -4,032.67 -5,100.48 5,940,094.67 524,888.03 0.70 4,032.67 MWD+IFR-AK-CAZ-SC(2) 8,850.09 65.16 231.94 4,902.77 4,770.47 -4,084.82 -5,168.14 5,940,042.26 524,820.59 0.84 4,084.82 MWD+IFR-AK-CAZ-SC(2) 8,942.14 65.15 231.08 4,941.44 4,809.14 -4,136.80 -5,233.52 5,939,990.01 524,755.43 0.85 4,136.80 MWD+IFR-AK-CAZ-SC(2) 9,035.15 65.05 230.95 4,980.60 4,848.30 -4,189.88 -5,299.09 5,939,936.68 524,690.07 0.17 4,189.88 MWD+IFR-AK-CAZ-SC(2) 9,127.23 65.09 230.49 5,019.42 4,887.12 -4,242.74 -5,363.73 5,939,883.57 524,625.65 0.46 4,242.74 MWD+IFR-AK-CAZ-SC(2) 9,221.17 65.11 229.97 5,058.97 4,926.67 -4,297.25 -5,429.22 5,939,828.81 524,560.38 0.50 4,297.25 MWD+IFR-AK-CAZ-SC(2) 9,312.93 65.51 229.15 5,097.30 4,965.00 -4,351.33 -5,492.67 5,939,774.48 524,497.15 0.92 4,351.33 MWD+IFR-AK-CAZ-SC(2) 9,405.58 65.69 229.53 5,135.57 5,003.27 -4,406.31 -5,556.68 5,939,719.25 524,433.37 0.42 4,406.31 MWD+IFR-AK-CAZ-SC(2) 9,497.49 65.81 230.36 5,173.32 5,041.02 -4,460.23 -5,620.82 5,939,665.08 524,369.45 0.83 4,460.23 MWD+IFR-AK-CAZ-SC(2) 9,590.87 65.72 231.45 5,211.65 5,079.35 -4,513.93 -5,686.90 5,939,611.13 524,303.59 1.07 4,513.93 MWD+IFR-AK-CAZ-SC(2) 9,683.59 65.68 231.89 5,249.81 5,117.51 -4,566.34 -5,753.19 5,939,558.46 524,237.52 0.43 4,566.34 MWD+IFR-AK-CAZ-SC(2) 9,775.20 65.90 232.40 5,287.38 5,155.08 -4,617.61 -5,819.16 5,939,506.93 524,171.76 0.56 4,617.61 MWD+IFR-AK-CAZ-SC(2) 9,867.85 66.06 232.85 5,325.09 5,192.79 -4,668.98 -5,886.41 5,939,455.30 524,104.72 0.48 4,668.98 MWD+IFR-AK-CAZ-SC(2) 9,961.14 66.16 231.58 5,362.87 5,230.57 -4,721.24 -5,953.82 5,939,402.77 524,037.52 1.25 4,721.24 MWD+IFR-AK-CAZ-SC(2) 10,051.54 66.19 230.79 5,399.39 5,267.09 -4,773.07 -6,018.26 5,939,350.69 523,973.30 0.80 4,773.07 MWD+IFR-AK-CAZ-SC(2) 10,145.71 66.28 231.55 5,437.34 5,305.04 -4,827.11 -6,085.40 5,939,296.39 523,906.38 0.74 4,827.11 MWD+IFR-AK-CAZ-SC(2) 10,236.74 66.19 232.36 5,474.02 5,341.72 -4,878.46 -6,151.00 5,939,244.79 523,840.99 0.82 4,878.46 MWD+IFR-AK-CAZ-SC(2) 10,330.63 66.23 231.82 5,511.90 5,379.60 -4,931.24 -6,218.79 5,939,191.74 523,773.42 0.53 4,931.24 MWD+IFR-AK-CAZ-SC(2) 10,423.27 65.62 231.21 5,549.69 5,417.39 -4,983.88 -6,285.00 5,939,138.85 523,707.43 0.89 4,983.88 MWD+IFR-AK-CAZ-SC(2) 10,514.58 65.14 230.74 5,587.73 5,455.43 -5,036.14 -6,349.48 5,939,086.33 523,643.16 0.70 5,036.14 MWD+IFR-AK-CAZ-SC(2) 10,609.10 65.41 229.58 5,627.26 5,494.96 -5,091.15 -6,415.40 5,939,031.07 523,577.46 1.15 5,091.15 MWD+IFR-AK-CAZ-SC(2) 10,699.26 65.28 228.87 5,664.87 5,532.57 -5,144.66 -6,477.45 5,938,977.32 523,515.63 0.73 5,144.66 MWD+IFR-AK-CAZ-SC(2) 10,794.28 65.34 228.06 5,704.57 5,572.27 -5,201.90 -6,542.08 5,938,919.82 523,451.24 0.78 5,201.90 MWD+IFR-AK-CAZ-SC(2) 10,886.37 65.44 225.53 5,742.92 5,610.62 -5,259.22 -6,603.10 5,938,862.27 523,390.46 2.50 5,259.22 MWD+IFR-AK-CAZ-SC(2) 10,977.51 65.33 222.76 5,780.89 5,648.59 -5,318.67 -6,660.80 5,938,802.60 523,333.00 2.77 5,318.67 MWD+IFR-AK-CAZ-SC(2) 11,071.39 65.73 220.11 5,819.78 5,687.48 -5,382.72 -6,717.34 5,938,738.33 523,276.72 2.60 5,382.72 MWD+IFR-AK-CAZ-SC(2) 11,162.31 66.81 216.72 5,856.38 5,724.08 -5,447.93 -6,769.04 5,938,672.92 523,225.29 3.61 5,447.93 MWD+IFR-AK-CAZ-SC(2) 11,255.99 69.05 213.09 5,891.58 5,759.28 -5,519.12 -6,818.68 5,938,601.54 523,175.93 4.31 5,519.12 M1IVD+IFR-AK-CAZ-SC(2) 11,348.83 71.53 210.29 5,922.90 5,790.60 -5,593.48 -6,864.57 5,938,527.00 523,130.34 3.90 5,593.48 MVVD+IFR-AK-CAZ-SC(2) 11,440.90 74.26 209.73 5,949.98 5,817.68 -5,669.68 -6,908.58 5,938,450.64 523,086.64 3.02 5,669.68 MWD+IFR-AK-CAZ-SC(2) 11,533.26 76.88 209.20 5,972.99 5,840.69 -5,747.55 -6,952.57 5,938,372.60 523,042.97 2.89 5,747.55 MWD+IFR-AK-CAZ-SC(2) 11,625.27 78.20 208.64 5,992.84 5,860.54 -5,826.19 -6,996.01 5,938,293.80 522,999.84 1.55 5,826.19 MWD+IFR-AK-CAZ-SC(2) 11,719.97 78.55 206.16 6,011.93 5,879.63 -5,908.53 -7,038.70 5,938,211.29 522,957.49 2.59 5,908.53 MVVD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 5 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit ND Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 11,811 21 78.26 204.63 6,030.27 5,897.97 -5,989.27 -7,077.03 5,938,130.41 522,919.49 1.67 5,989.27 MWD+IFR-AK-CAZ-SC(2) 11,905.50 77.24 203.30 6,050.27 5,917.97 -6,073.47 -7,114.45 5,938,046.07 522,882.40 1.75 6,073.47 MWD+IFR-AK-CAZ-SC(2) 11,997.63 76.96 200.88 6,070.84 5,938.54 -6,156.67 -7,148.22 5,937,962.74 522,848.96 2.58 6,156.67 MWD+IFR-AK-CAZSC(2) 12,090.29 76.40 199.58 6,092.19 5,959.89 -6,241.27 -7,179.40 5,937,878.03 522,818.12 1.49 6,241.27 MWD+IFR-AK-CAZSC(2) 12,184.40 78.38 197.58 6,112.74 5,980.44 -6,328.32 -7,208.66 5,937,790.87 522,789.22 2.95 6,328.32 MWD+IFR-AK-CAZSC(2) 12,275.51 81.43 195.44 6,128.71 5,996.41 -6,414.31 -7,234.14 5,937,704.79 522,764.08 4.07 6,414.31 MVVD+IFR-AK-CAZ-SC(2) 12,368.61 83.97 192.11 6,140.54 6,008.24 -6,503.98 -7,256.11 5,937,615.04 522,742.47 4.48 6,503.98 MWD+IFR-AK-CAZ-SC(2) 12,461.58 84.42 189.67 6,149.95 6,017.65 -6,594.80 -7,273.58 5,937,524.16 522,725.36 2.66 6,594.80 MWD+IFR-AK-CAZ-SC(2) 12,505.86 83.36 189.18 6,154.66 6,022.36 -6,638.23 -7,280.79 5,937,480.71 522,718.32 2.63 6,638.23 MWD+IFR-AK-CAZ-SC(2) 12,560.27 83.66 187.55 6,160.81 6,028.51 -6,691.72 -7,288.66 5,937,427.20 522,710.67 3.02 6,691.72 7-5/8"x 9-7/8"- 0 12,591.24 83.84 186.63 6,164.18 6,031.88 -6,722.27 -7,292.46 5,937,396.63 522,706.99 3.02 6,722.27 MWD+IFR-AK-CAZ-SC(2) 12,629.75 84.98 184.32 6,167.93 6,035.63 -6,760.41 -7,296.12 5,937,358.48 522,703.49 6.66 6,760.41 MWD+IFR-AK-CAZ-SC(2) 12,679.03 87.40 183.52 6,171.20 6,038.90 -6,809.47 -7,299.48 5,937,309.42 522,700.32 5.17 6,809.47 MWD+IFR-AK-CAZ-SC(2) 12,724.64 89.62 182.07 6,172.39 6,040.09 -6,855.00 -7,301.70 5,937,263.87 522,698.28 5.81 6,855.00 MWD+IFR-AK-CAZ-SC(2) 12,816.07 90.90 181.48 6,171.98 6,039.68 -6,946.39 -7,304.53 5,937,172.49 522,695.81 1.54 6,946.39 MWD+IFR-AK-CAZ-SC(2) 12,911.54 91.55 180.78 6,169.93 6,037.63 -7,041.81 -7,306.41 5,937,077.06 522,694.31 1.00 7,041.81 MWD+IFR-AK-CAZ-SC(2) 13,006.41 91.99 180.22 6,167.00 6,034.70 -7,136.64 -7,307.24 5,936,982.25 522,693.86 0.75 7,136.64 MWD+IFR-AK-CAZ-SC(2) 13,101.12 91.51 180.71 6,164.11 6,031.81 -7,231.30 -7,308.01 5,936,887.60 522,693.47 0.72 7,231.30 MWD+IFR-AK-CAZ-SC(2) 13,196.24 91.34 181.28 6,161.75 6,029.45 -7,326.37 -7,309.66 5,936,792.52 522,692.20 0.63 7,326.37 MWD+IFR-AK-CAZ-SC(2) 13,291.11 90.89 181.55 6,159.90 6,027.60 -7,421.20 -7,312.00 5,936,697.70 522,690.23 0.55 7,421.20 MWD+IFR-AK-CAZ-SC(2) 13,385.67 90.04 181.02 6,159.13 6,026.83 -7,515.73 -7,314.12 5,936,603.17 522,688.49 1.06 7,515.73 MWD+IFR-AK-CAZ-SC(2) 13,480.59 88.10 180.83 6,160.67 6,028.37 -7,610.62 -7,315.66 5,936,508.28 522,687.33 2.05 7,610.62 MWD+IFR-AK-CAZSC(2) 13,574.63 88.19 180.87 6,163.72 6,031.42 -7,704.60 -7,317.05 5,936,414.31 522,686.31 0.10 7,704.60 MWD+IFR-AK-CAZ-SC(2) 13,670.16 87.29 181.79 6,167.48 6,035.18 -7,800.03 -7,319.27 5,936,318.88 522,684.48 1.35 7,800.03 MWD+IFR-AK-CAZSC(2) 13,765.15 86.90 182.48 6,172.30 6,040.00 -7,894.83 -7,322.80 5,936,224.08 522,681.32 0.83 7,894.83 MWD+IFR-AK-CAZSC(2) 13,859.77 88.51 182.83 6,176.09 6,043.79 -7,989.27 -7,327.18 5,936,129.63 522,677.32 1.74 7,989.27 MWD+IFR-AK-CAZSC(2) 13,953.90 87.71 183.51 6,179.19 6,046.89 -8,083.20 -7,332.38 5,936,035.69 522,672.49 1.12 8,083.20 MWD+IFR-AK-CAZSC(2) 14,048.87 88.18 182.73 6,182.60 6,050.30 -8,177.97 -7,337.55 5,935,940.91 522,667.70 0.96 8,177.97 MWD+IFR-AK-CAZSC(2) 14,143.49 88.56 182.91 6,185.29 6,052.99 -8,272.44 -7,342.20 5,935,846.43 522,663.42 0.44 8,272.44 MWD+IFR-AK-CAZSC(2) 14,237.01 88.53 183.32 6,187.66 6,055.36 -8,365.79 -7,347.28 5,935,753.07 522,658.72 0.44 8,365.79 MWD+IFR-AK-CAZSC(2) 14,331.75 88.43 182.50 6,190.18 6,057.88 -8,460.37 -7,352.09 5,935,658.48 522,654.29 0.87 8,460.37 MWD+IFR-AK-CAZSC(2) 14,427.36 88.87 181.93 6,192.43 6,060.13 -8,555.88 -7,355.78 5,935,562.96 522,650.97 0.75 8,555.88 MWD+IFR-AK-CAZSC(2) 14,521.73 88.21 183.33 6,194.83 6,062.53 -8,650.12 -7,360.11 5,935,468.72 522,647.02 1.64 8,650.12 MWD+IFR-AK-CAZ-SC(2) 14,617.01 89.04 182.89 6,197.12 6,064.82 -8,745.23 -7,365.28 5,935,373.60 522,642.23 0.99 8,745.23 MWD+IFR-AK-CAZ-SC(2) 14,711.17 88.46 182.17 6,199.17 6,066.87 -8,839.27 -7,369.43 5,935,279.55 522,638.45 0.98 8,839.27 M1M3+IFR-AK-CAZ-SC(2) 14,805.41 88.73 181.94 6,201.49 6,069.19 -8,933.43 -7,372.81 5,935,185.39 522,635.45 0.38 8,933.43 MWD+IFR-AK-CAZ-SC(2) 14,898.98 89.01 181.73 6,203.33 6,071.03 -9,026.93 -7,375.81 5,935,091.89 522,632.82 0.37 9,026.93 MWD+IFR-AK-CAZ-SC(2) 14,994.56 88.84 181.38 6,205.12 6,072.82 -9,122.46 -7,378.40 5,934,996.36 522,630.61 0.41 9,122.46 MWD+IFR-AK-CAZ-SC(2) 15,090.36 87.47 181.16 6,208.21 6,075.91 -9,218.18 -7,380.52 5,934,900.64 522,628.87 1.45 9,218.18 MWD+IFR-AK-CAZ-SC(2) 9/26/2014 9:45:40AM Page 6 COMPASS 5000.1 Build 65 t III Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2E-01 Project: Kuparuk River Unit TVD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Site: Kuparuk 2E Pad MD Reference: 2E-01:105.1+27.2 @ 132.30usft(Doyon 141) Well: 2E-01 North Reference: True Wellbore: 2E-01 Survey Calculation Method: Minimum Curvature Design: 2E-01 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,185.59 86.95 181.18 6,212.84 6,080.54 -9,313.28 -7,382.47 5,934,805.54 522,627.31 0.55 9,313.28 MWD+IFR-AK-CAZ-SC(2) 15,280.69 87.60 180.98 6,217.36 6,085.06 -9,408.25 -7,384.26 5,934,710.57 522,625.89 0.72 9,408.25 MWD+IFR-AK-CAZ-SC(2) 15,375.89 88.58 180.34 6,220.54 6,088.24 -9,503.39 -7,385.35 5,934,615.44 522,625.18 1.23 9,503.39 MWD+IFR-AK-CAZ-SC(2) 15,469.15 91.33 179.33 6,220.61 6,088.31 -9,596.64 -7,385.08 5,934,522.20 522,625.82 3.14 9,596.64 MWD+IFR-AK-CAZ-SC(2) 15,563.95 90.90 180.08 6,218.77 6,086.47 -9,691.42 -7,384.60 5,934,427.43 522,626.68 0.91 9,691.42 MWD+IFR-AK-CAZ-SC(2) 15,660.31 90.00 181.33 6,218.01 6,085.71 -9,787.77 -7,385.78 5,934,331.09 522,625.88 1.60 9,787.77 MWD+IFR-AK-CAZ-SC(2) 15,753.64 89.66 180.31 6,218.29 6,085.99 -9,881.09 -7,387.12 5,934,237.77 522,624.91 1.15 9,881.09 MWD+IFR-AK-CAZ-SC(2) 15,848.11 90.35 179.83 6,218.28 6,085.98 -9,975.56 -7,387.23 5,934,143.31 522,625.17 0.89 9,975.56 MWD+IFR-AK-CAZ-SC(2) 15,943.86 90.18 180.00 6,217.83 6,085.53 -10,071.31 -7,387.09 5,934,047.58 522,625.70 0.25 10,071.31 MWD+IFR-AK-CAZ-SC(2) 16,038.11 88.91 181.15 6,218.58 6,086.28 -10,165.54 -7,388.04 5,933,953.34 522,625.13 1.82 10,165.54 MWD+IFR-AK-CAZ-SC(2) 16,133.12 88.18 180.47 6,221.00 6,088.70 -10,260.51 -7,389.38 5,933,858.38 522,624.16 1.05 10,260.51 MWD+IFR-AK-CAZ-SC(2) 16,226.50 87.36 181.03 6,224.63 6,092.33 -10,353.81 -7,390.60 5,933,765.09 522,623.31 1.06 10,353.81 MWD+IFR-AK-CAZ-SC(2) 16,320.83 87.29 181.00 6,229.03 6,096.73 -10,448.03 -7,392.27 5,933,670.88 522,622.02 0.08 10,448.03 MWD+IFR-AK-CAZ-SC(2) 16,414.45 88.19 182.70 6,232.72 6,100.42 -10,541.52 -7,395.29 5,933,577.38 522,619.37 2.05 10,541.52 MWD+IFR-AK-CAZ-SC(2) 16,507.28 88.87 185.06 6,235.11 6,102.81 -10,634.10 -7,401.57 5,933,484.79 522,613.46 2.64 10,634.10 MWD+IFR-AK-CAZ-SC(2) 16,602.94 89.04 186.14 6,236.85 6,104.55 -10,729.29 -7,410.90 5,933,389.57 522,604.51 1.14 10,729.29 MWD+IFR-AK-CAZ-SC(2) 16,697.61 90.24 186.43 6,237.45 6,105.15 -10,823.38 -7,421.27 5,933,295.44 522,594.52 1.30 10,823.38 MVVD+IFR-AK-CAZ-SC(2) 16,791.90 90.11 185.85 6,237.16 6,104.86 -10,917.13 -7,431.35 5,933,201.67 522,584.81 0.63 10,917.13 MWD+IFR-AK-CAZ-SC(2) 16,886.48 88.91 185.77 6,237.97 6,105.67 -11,011.22 -7,440.92 5,933,107.55 522,575.61 1.27 11,011.22 MWD+IFR-AK-CAZ-SC(2) 16,980.86 88.43 185.23 6,240.16 6,107.86 -11,105.14 -7,449.97 5,933,013.60 522,566.94 0.77 11,105.14 MWD+IFR-AK-CAZ-SC(2) 17,074.50 88.32 184.80 6,242.81 6,110.51 -11,198.38 -7,458.15 5,932,920.34 522,559.13 0.47 11,198.38 MWD+IFR-AK-CAZ-SC(2) 17,169.47 89.15 184.22 6,244.91 6,112.61 -11,293.03 -7,465.62 5,932,825.67 522,552.04 1.07 11,293.03 MWD+IFR-AK-CAZ-SC(2) 17,263.82 89.15 184.42 6,246.31 6,114.01 -11,387.11 -7,472.72 5,932,731.58 522,545.31 0.21 11,387.11 MVVD+IFR-AK-CAZ-SC(2) 17,359.41 88.56 183.38 6,248.22 6,115.92 -11,482.45 -7,479.22 5,932,636.21 522,539.19 1.25 11,482.45 MWD+IFR-AK-CAZ-SC(2) 17,455.33 88.32 182.06 6,250.83 6,118.53 -11,578.23 -7,483.77 5,932,540.43 522,535.02 1.40 11,578.23 MWD+IFR-AK-CAZ-SC(2) 17,550.54 88.49 182.08 6,253.48 6,121.18 -11,673.34 -7,487.21 5,932,445.32 522,531.96 0.18 11,673.34 MVVD+IFR-AK-CAZ-SC(2) 17,644.99 88.94 181.80 6,255.60 6,123.30 -11,767.71 -7,490.41 5,932,350.94 522,529.14 0.56 11,767.71 MWD+IFR-AK-CAZ-SC(2) 17,740.48 89.04 182.67 6,257.28 6,124.98 -11,863.11 -7,494.13 5,932,255.53 522,525.80 0.92 11,863.11 MWD+IFR-AK-CAZ-SC(2) 17,834.47 89.04 183.58 6,258.86 6,126.56 -11,956.95 -7,499.25 5,932,161.69 522,521.05 0.97 11,956.95 MWD+IFR-AK-CAZ-SC(2) 17,929.21 89.01 182.59 6,260.47 6,128.17 -12,051.54 -7,504.35 5,932,067.09 522,516.33 1.05 12,051.54 MWD+IFR-AK-CAZ-SC(2) 18,023.30 89.63 184.51 6,261.59 6,129.29 -12,145.43 -7,510.18 5,931,973.18 522,510.88 2.14 12,145.43 MWD+IFR-AK-CAZ-SC(2) 18,118.61 90.00 185.57 6,261.89 6,129.59 -12,240.37 -7,518.55 5,931,878.22 522,502.88 1.18 12,240.37 MVVD+IFR-AK-CAZ-SC(2) 18,212.69 89.97 182.60 6,261.92 6,129.62 -12,334.20 -7,525.25 5,931,784.37 522,496.56 3.16 12,334.20 MWD+IFR-AK-CAZ-SC(2) 18,307.18 90.59 181.13 6,261.46 6,129.16 -12,428.64 -7,528.33 5,931,689.93 522,493.86 1.69 12,428.64 MWD+IFR-AK-CAZ-SC(2) 18,400.48 90.53 179.93 6,260.54 6,128.24 -12,521.93 -7,529.19 5,931,596.65 522,493.37 1.29 12,521.93 MWD+IFR-AK-CAZ-SC(2) 18,496.70 88.67 179.05 6,261.22 6,128.92 -12,618.14 -7,528.33 5,931,500.45 522,494.61 2.14 12,618.14 MWD+IFR-AK-CAZ-SC(2) 18,590.61 87.84 179.42 6,264.08 6,131.78 -12,712.00 -7,527.08 5,931,406.61 522,496.23 0.97 12,712.00 MWD+IFR-AK-CAZ-SC(2) 18,650.00 87.84 179.42 6,266.31 6,134.01 -12,771.34 -7,526.48 5,931,347.28 522,497.07 0.00 12,771.34 4-1/2"x 6-3/4" 18,670.00 87.84 179.42 6,267.07 6,134.77 -12,791.33 -7,526.28 5,931,327.29 522 497.35 0.00 12,791.33 PROJECTED to TD 9/26/2014 9:45:40AM Page 7 COMPASS 5000.1 Build 65 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Thursday, March 19, 2015 1:13 PM To: Callahan, Mike S (Mike.Callahan@conocophillips.com) Subject: KRU 2E-01 10-407 Surface casing cement Mike, Could you please tell me if there was cement to surface on the surface cement job and if so how much was returned? 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.LoeppCa2alaska.aov • 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 1 • 0 24k,°13co ConocoPhilli s RECEIVED TRANSMITTAL OCT 082014 -CONFIDENTIAL DATA `AJoT— /� ��^-++��^++ FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender r - ���1�V ConocoPhillips Alaska, Inc. CC �� P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 DATA LOGGEC (o/% /2012( RE: 2E-01 M.K.BENDER DATE: 10/06/2014 Transmitted: jKuparuk River Unit, Alaska 2E--01 h� 1 hardcopy report and 1 CD !u' 7 Il CANRIG Final well report mud logging data for 2E-01; 9/08/2014; table of contents, mud logging equipment; general ll. I well details, geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation logs; color 1 log presentations, IIFormation log MD&TVD 1 jGas ratio MD&TVD II li0 Combo log MD&TVD Drilling dynamics MD&TVD t CD contains daily reports, DML data,final well report, LAS files, Log PDF files, remarks, TIFF files, show report II Please promptly sign, scan and return electronically to Sandra.D.Lemke000P.com I t n CC: 2E-01 transmittal folder, production well files, eSearch Receipt: '" / e: ‘o loG it ai GIS-Technical Data Management I ConocoPhillips (Anchorage,Alaska I Ph:9072654947 1110 Ferguson, Victoria L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 09, 2014 2:40 PM To: Callahan, Mike S; Ferguson,Victoria L(DOA) Subject: RE: 2E-01 (PTD#214-076)Intermediate Cement Job Update/Question Follow Up Flag: Follow up Flag Status: Flagged No ..you are good to go as per our phone call. If you do not get a good FIT at drill out then contact us however. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Callahan, Mike S [ 'conocophillips.com] Sent: Tuesday, September 09, 2014 2:38 PM To: Ferguson, Victoria L(DOA); Schwartz, Guy L(DOA) Subject: 2E-01 (PTD # 214-076) Intermediate Cement Job Update/Question Victoria/Guy, We completed our cement job on our 7-5/8" intermediate casing on 2E-01 last night with Doyon 141. The job pumped according to plan,with casing reciprocation throughout the job and full returns, but our top plug did not bump. We pumped half the shoe track volume over the calculated displacement but saw no indication the plug had landed. We shut the well in and waited until our cement built 500 psi compressive strength in the UCA cell before moving on to any other operations. I just wanted to double check with you if there is any report we need to file or any other actions we need to take before proceeding to drill out our production hole. We have about a day and a half of drill pipe lay down/pick up and BOP testing before we will be ready to drill out. Could you please let me know if the AOGCC requires any action on our part before proceeding? Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 1 • • PTO al ¢- C-7-4- Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Friday, August 29, 2014 2:41 PM To: 'Callahan, Mike S' Subject: RE: Doyon 141 diverter layout on 2E-01 Thanx;this is what I need. Looks like a straight shot- Original Message From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Friday,August 29, 2014 2:01 PM To: Ferguson,Victoria L(DOA) Subject: Fwd: Doyon 141 diverter layout on 2E-01 Victoria, here is a schematic of the diverter on Doyon 141. Let me know if this is what you were looking for. Thanks, Mike Begin forwarded message: From: Doyon 141 Company Man<n1334@conocophillips.com<mailto:n1334@conocophillips.com» Date:August 29, 2014 at 12:51:35 PM AKDT To: "Callahan, Mike 5"<Mike.Callahan@conocophillips.com<mailto:Mike.Callahan@conocophillips.com>> Subject: Doyon 141 diverter layout on 2E-01 Mike, I hope this works for you. Robert Wall Andy Lundale Doyon 141 Rig Supervisors 670-4963 Camp Office 670-4976 Rig Floor 1 . ' # . . • • 0 N.- in 01-.1. .o r-t .Y y5 ri t 11 Y t 14 1101 a I O 4 0 0 li . Bi DI II g Di 101t § * 171-"-- ;gii 4 1 r U i o c 1 Q c N h li 1` F' 1 - *a } N• din __a + cinippen Li101 101 -------------------- 1 J "saes=Ei 1 El 921611101 --1 ii 9 h i-Fn y-µ- 1 1 rED tet-' MI ti .1 F ,r •0 t . - 4 rs o ` � THE STATE• • A>. a c;�� e f a. cd ',L-1---'ac 7 v r ip , f, a,, �Tr� n-n, -""3 -7- \ , ., _ 1 J I—' I. a_,\_,�� .., • f 333 west Sevensh Avenue F GOVERNOR SEAN PAR\'LLL Anchorage, Alaska 99501-3572 '' Main: 907.279.1433 ®p,41-A,67'. Fox: 907 2-0 7042 G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2E-01 ConocoPhillips Alaska, Inc. Permit No: 214-076 Surface Location: 4775' FNL, 5120' FEL, SEC. 36, T11N, RO9E, UM Bottomhole Location: 1285' FNL, 2096' FEL, SEC. 15, T1ON, RO9E, 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 414 P .-- Cathy 1 Foerster Chair DATED this S day of August, 2014. 0 0 RECEIVED e STATE OF ALASKA JUN 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION g14I PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: lb Proposed Well Class: Development-Oil D. Service-Winj ❑ Single Zone ❑. 1 c.Specify if well is proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: LJ Blanket L_I Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc.. Bond No. 59-52-180• MU 2E-01 OK 3.Address: 6.Proposed Depth: 12. Field/Pool(s): (.J3/v4 P.O. Box 100360 Anchorage,AK 99510-0360 MD: 18266' • TVD: 6280' \ Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property D4ggriation( esg3�1 502�ber): �Y,IE,r Surface:4775'FNL,5120'FEL,Sec.36,T11 N, RO9E, UM • ADL 25658,2566665,((2.02664Kuparuk^Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 654'FNL, 1831'FEL,Sec. 10,T10N, RO9E,UM 2584,2586,2178 8/1/2014 Total Depth: 9.Acres in Property: 44t3 14.Distance to 1285'FNL,2096'FEL,Sec. 15,T1 ON, RO9E, UM , 2660- /0r ky0 Nearest Property: <1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 134 feet 15.Distance to Nearest Well Open Surface:x- 529972 y- 5944147 Zone- 4 • GL Elevation above MSL: • 106 feet to Same Pool: 2F-18L1 ,4350' 16.Deviated wells: Kickoff depth: • 395 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 91° deg Downhole:3800 psig , Surface:3186 psig , 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) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' Coldset II 13.5" 10.75" 45.5# L-80 Hyd 563 4788' 28' 28' 4816' 3225' 1755 sx ALC, 195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hyd 563 11413' 28' 28' 11436' 5950' _412 sx Class G 9.875" 7.625' 39# TN-110 Hyd 563 1000' 11436' 5950' 12436' 6152' same as above 6.5" 4.5" 12.6# L-80 Hyd 563 6031' 11615' 6000' 18271' 6285' frac sleeve 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat ❑ BOP Sketch❑ Drilling Prograrr ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: (O/Zi)`t 22. I hereby certify that the foregoing is true and correct. Contact Lindsey Hunter @ 263-64270604 Email Lindsey.Hunter(a�conocophillips.com Printed Nam G. L. Alvord Title Alaska Drilling Manager Signature t �('N1•"� Phone:265-6120 Date 6 (2 f?o(4 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 0211 0?-*C;) 50- art-0235 / a. -co -00 Date: '-j-2 O k 4 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales: Other: I34P .71-e..5./ to 3 6-60 p 5 i Samples req'd: Yes No j Mud log req'd: Yes❑ No[ N0 i-T 4-OLZL'G .f fottr`->"e-elf a is H2S measures: Yes No ❑r--j Directional svy req'd: Yes[ No El ea 51 v er.4.ne t d e ta' 15 Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No ,.t h cvr it/o vinl C f • v fa C la -403 c',.pdv t icG� va Ic( f' f .,,v, P R VE BY THE Approved by: COMMISSSI � IG�N Date: 9 --S -/y Form 10-401 ( vised 10/2012) This permit is valid'' 24 raohthc.lyd t at isapproval(20 C .005(g)) IVs-F 8////9- �W� tor.54( - ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 July 30,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2E-01,A Kuparuk A5 Sand Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2E pad. The expected spud date for this well is August 1st,2014.It is planned to use Rig Doyon 141. 2E-01 is planned to be a horizontal Kuparuk A5 sand producer.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-4,816'MD/3,225'TVD. The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 12,440'MD/6,157'TVD.The production hole will be drilled with 6-1/2"bit and run 4-1/2"liner to+/- 18,271'MD/6,285'TVD. The production lateral will be fractured using drillable fracture sleeves(drop ball system)and swell packers. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. Pressure information as required by 20 ACC 25.035(d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Callahan at 263-4180 (Mike.Callahanna,ConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager ! • Application for Permit to Drill Document Kuparuk Well 2E-01 Well Name Requirements of 20 AAC 25.005(fl The well for which this application is submitted will be designated as 2E-01 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identitying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4775'FNL, 5120'FEL, Sec 36, T 11N,R009E,UM NGS Coordinates RKB Elevation 131'AMSL Northings: 5,944,147.30' Eastings: 529,972.35' Pad Elevation 106'AMSL Location at Top of 654' FNL, 1831'FEL,Sec 10,T1ON,R009E,UM Productive Interval (Kuparuk A5 Sand) NGS Coordinates Measured Depth, RKB: 12,345' Northings: 5,937,683.78' Eastings:522,731.92' Total Vertical Depth, RKB: 6,143' Total Vertical Depth, SS: 6,009' Location at Total Depth 1285'FNL, 2096'FEL, Sec 15,T1ON,R009E,UM NGS Coordinates Measured Depth, RKB: 18,266' Northings: 5,931,772.81' Eastings:522,494.88' Total Vertical Depth, RKB: 6,280' Total Vertical Depth, SS: 6,146' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(bl If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable: Please reference BOP schematics on file for Doyon 141. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2E-01 is calculated using an estimated maximum reservoir pressure of 3,800 psi (11.9 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,143' TVD (WP04): A Sand Estimated. BHP = 3,800 psi A Sand estimated depth(WP04) =6,143' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =614 psi (6,143' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,186 psi (3,800 psi—614 psi) (B)data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (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; See attached 2E-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) Sizet(Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/ 106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 4,788 Surf 4,816/3,225 1,755 sx ALC Lead 11.02 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg 7-5/8 9-7/8 29.7 L-80 563i1 11,413 Surf 11,436/5,950 Continued from below TN Hydril 412 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 39 110 563 1,000 11,436/5,950 12,436/6,152 10,918'MD 4 1/2 6-1/2 12.6 L-80 Hydril 6 031 11,615/6,000 18,271/6,285 Drillable Frac Sleeve(ball drop system) 563 with swell packers s S Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2"Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5- 11.5 10.6- 11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. • Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) .In application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. 0 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-4,811' MD/3,220' TVD as per directional plan (wp04). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIB and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 10,695'MD/5,666' TVD,back ream to the surface shoe at 4,811' MD ensuring a clean hole(this will allow us to drill and clean up the shales quickly,reducing exposure time). 9. RIH to top of HRZ and directionally drill to 12,345' MD/6,143' TVD,landing in the Kuparuk A5 sand. Wellsite geologist will call intermediate TD. Circulate and rotate until shakers are clean. Short trip to top of shales at 10,695' MD on elevators,if no tight spots encountered continue to POOH. (If tight spots are encountered,back ream through only tight areas to top of HRZ,run back to bottom and circulate bottoms up.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD at 12,436'MD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 10,918'MD(500'MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,stethoscope,periscope, microscope,and neutron density) 18. RIH and clean out cement to 100'above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-1/2"hole geosteering though the Kuparuk A5 sand to TD 18,266'MD as per directional plan(wp04). 21. Circulate hole clean and POOH. 22. Lay down Production BHA. 23. PU and run 4-1/2", 12.6#,Hydril 563 liner with drillable frac sleeves(ball drop system). The top of liner will be placed at 12,236'MD,allowing for 200' of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. • 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well(1R- 18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification.(659-7212). Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic • • Ferguson, Victoria L (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday,July 30, 2014 2:49 PM To: Ferguson,Victoria L(DOA) Cc: Hunter, Lindsey L Subject: RE:2E-01 (PTD 214-076) Attachments: 2E-01 Permit to Drill .doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, My apologies for not responding to this sooner, I was out of town when Lindsey forwarded it to me and just realized that I hadn't gotten back to you. Please see the revised PTD attached. In response to your questions: 1. The BOP's will be tested to 3500 psi. 2. The maximum potential reservoir pressure is 11.9 ppg, but we do not expect the pressure to be that high. If pressure that high is encountered, it will be towards the toe of the lateral (pressure is expected to climb from —8.5 ppg at the intermediate shoe). Mud weight will be adjusted up accordingly in the event the maximum pressure is observed, up to 12.0 ppg if necessary. The reservoir is very tight, and pressure increase should be gradual as there are no sealing faults expected to be crossed,so any pressure higher than expected should be easily manageable. 3. Cement yields: a. Surface: i. Lead slurry: Arctic LiteCRETE @ 11.02 ppg yielding 1.93 ft3/sk ii. Tail slurry: DeepCRETE @ 12.0 ppg yielding 1.63 ft3/sk b. Intermediate: i. Class G @ 15.8 ppg yielding 1.16 ft3/sk Please let me know if you need any more information on this well. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Hunter, Lindsey L Sent: Wednesday, July 2, 2014 12:27 PM To: Callahan, Mike S Subject: FW: 2E-01 (PTD 214-076) 1 4110 Lindsey Hunter • Drilling Engineer ConocoPhillips Alaska D&W 907-265-6427 lindsey.hunter@conocophillips.com From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Tuesday, July 01, 2014 11:16 AM To: Hunter, Lindsey L Subject: [EXTERNAL]2E-01 (PTD 214-076) Lindsey, 1. The MPSP is 3186 psi but the BOPs are only being tested to 3000 psi. 2. The maximum formation pressure is 11.9 ppg EMW while the planned mud weight is 10.6 to 11.5 ppg. 3. Please provide cement details including yield. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson(a�alaska.00v 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 Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 • • ot Zp. CO asQ o0- .= L ,21 CO V ami ° ti' E L ccs a Q J => CO 0 LNW O O O 0 Y L i N N N w� >, o a IFS a co S ca - = V a Y Y F. a Q. 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C ca (u!/09'Z)Jo}oez uo!leaedag Q U oRIGI \ AL SMD Inc Azi TVD +N/-S -.E/-W DLeg TFac�Sec Target � 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.0 0.0028 395 2E-01wp04 2 395.00 0.00 0.00 395.00 0.00 0.00 0.00 0.00 0.00 3 795.73 6.01 230.00 795.00 -13.50 -16.09 1.50 230.00 13.50 395 995 • 4 1748.47 29.83 230.00 1695.00 -200.58 -239.04 2.50 0.00 200.58 28.00 To 18266.43 5 2766.38 65.43 231.79 2370.01 -664 68 -815.38 3.50 2.80 664.68 6 10832.89 65.43 231.79 5723.50 -5202.51 -6579.99 0.00 0.00 5202.51 995 1495 7 12435.82 85.00 186.00 6152.00 -6526.04 -7277.64 3.00 -73.65 6526.04 2F-22 220ct13 PB T1 1495 -----"" 2095 1 5.25,Mav 07 2014 9 12620.19 91.17 185.92 6159.76 -6709.14 -7296.78 4.00 -0.74 6709.14 10 12999.02 91.17 185.92 6152.00 -7085.87 -7335.85 0.00 0.00 7085.87 2F-22 220ct13 PB T2 2095 2595 11 13352.01 88.47 179.01 6153.11 -738.29 -7351.03 2.10 -111.40 7438.29 12 13939.11 88.47 179.01 6168.83 -8025.08 -7340.91 0.00 0.00 8025.08 GLOBAL FILTER APPLIED; 14 14037.01 89.00 181.00 6171.00 -8161.19 -7341.84 2.10 102.90 816119 2F-22220ct13P8 13 2595 3195 15 15351.66 88.83 181.75 6197.80 -9436.73 -7380.71 0.00 0.00 9436.73 3195 3695 Depth From Depth To spn,aYrRan Tool 16 15414.94 89.00 183.00 6199.00 -9499.94 -7383.33 2.00 82.26 9499.94 2F-22 220ct13 PB T4 20.88 99600 2E-01 wp04(Plan:2E-01) GYD-GC-S6 17 15449.07 88.35 182.80 6199.79 -9534.02 -7385.06 2.00 -163.06 9534.02 3695 4295 995.00 2495.00 2E-01wp04(Plan.0E-01) MD 18 17010.76 88.35 182.80 6244.84 -11093.20 -7461.34 0.00 0.00 11093.20 995.00 4476.61 2E-01wp04(Plan.2E-01) MwD.IFP-ac-CAz-SC 19 17016.38 88.40 182.90 6245.00 -11098.80 -7461.62 2.00 61.81 11098.80 2F-22 220ct13 PB T5 4295 5395 4476.61 5976.61 2E-01wp04(Plan.2E-01) MWD 20 17020.27 88.40 182.98 6245.11 -11102.69 -7461.82 2.00 93.26 11102.69 4476.61 12435.02 2E-01wp04(Mem 2E-0M MW0.IF14-a(-CAOSC 21 18266.18 88.40 182.98 6279.99 -12346.43 -7526.52 0.00 0.00 12346.43 12436 82 13935-e2 2E01wg04(Plan:2E-01) MwD 22 18266.43 88.40 182.98 6280.00 -12346.68 -7526.53 2.00 27.40 12346.68 2F-22 220ct13 PB T6 5395 6395 12435.82 10266.43 2E-01wp04(Plan:2E-01) MWD.IFa-AKCALSC CASING DETAILS 6395 7495 TVD MD Name Size 3220.00 4810.96 10-3/4"x13-1/2" 10-3/4 7495 8495 6152.00 12435.82 7-5/8"x9-7/8" 7-5/8 6280.00 18266.43 3-1/2"x6-3/4" 3-1/2 8495 9595 12E-041 12E-07 12E-02wp031 9595 10695 12E-04PB1 , �, E1 ./ 10695 11695 01,360 ,' 12E-03I 11695 - -- 12768 7 7 12768 13495 /1,///00:00:111t 1 0 ,® I 13495 14295 / �11•0 !,,-1,,:i -30/330 rilli$.010.01-`-.0.-;,:;.:4,/ e'. 11F,41 30 f2E-06L1-01_wp02 14295 14995 rlierk'i'Ir' ;b'- t,:s. 4 14995 15695 Il iiiiitih--4-..����e - ����y 14 .• •. �� r OE,-0,61 ) r l'o ♦• :����� C e., �'i. ' 15695 16495 ��h ,',004;44,fel \\�\N�; .t`I!eimmigitlaca" i��,wi _ 16495 17195 Ittt e,V,X �2E-06 1 .ie eeaN♦ 9 14t s cfoS �X/1. 17195 17995 17995 18495 4meeo0e0i�1•� 9eilrt lNHleoa® -14'eN ve�e1�� s ��\ ,il _ Nt•.•e '111 n` a P ���_� -60/300 ,� ic 11,44ej ), /` �04;rip\�,,,,.tvii),_ 60 -.Ktl..4,440.1t44,„hil 90/270 iii 90 K6J 120/240 80 �/ 120 90 ,/ 100 110 120 130 -150/210 140 150 150 -180/180 4- 2E $ 25 .e. 2E-06,2E-061.1-01,2E-C6_1-01,p029a "� 2E $ 26 -tr 2EU:.E�:E81VO it 2 :E E V; -111- 2E E-0;V; 1- Plan ;PTL 21.2.21wpOOV4 4- 2Ea4.2Ea2Pa,.20Aa�100 .. 26o.2Eaao,.2En„.aa� $ 2cyR I G I t90L0252200505500 $ 2E9,wpo. S 8 N M M 1 i sad 2 e o�.g..-o.o.a e <`n i3aaaa� aaac� 228888:•000 y . . . . . . . O .6-E mm CD N{N{pp N N�N�pp. N N N N ....-._-- _...__.....__ --........... 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C•' O ia. mo — O co a !0`1181 jl q O NN ..I J r I .� LI.LL - `N N ,CV O \r O v ' NN m p O O O O O E O O O O O cLO O Ln O Ln c N Ln I� O N T 1 I I T T (ui/ll 005y ) ( ) 1.10N/HLITnoS I 1 t \ IarII1i / L. • • • • f • • . 0 0 0 0. 3 f m .\/ED ro N 1 • • 2E-01 wp04 Surface Location IoIo1, t � CPA[Coordinat Co. �, .uea , ,� � , From: __ To: Datum: 1NAD27 Region: 'alaska .i Datum: !NAD27 _ Region: ,alaska j C LatitudelLongitude 'Decimal Degrees u ._1 r Latitude/Longitude 'Decimal Degrees .' C UTM Zone:1 E South r UTM Zone:ITrue (— South ( State Plane Zone:14 w Units: us-ft . r State Plane Zone:'True Units: 'us-ft �1 1 f i Legal Description(NAD 27 only) C. Legal Description(NAD27 only) -Starting Coordinates: ----- — —Legal Description — X: 1529972.35 Township: 1011 IN . Range: 009 1E .'.1 5944147.30 Y: �``'�� d I 1 Meridian: lU Section:136 e IFNL .I 14775.0763 IFEL . 15119.8480 Transform I Quit Help 2E-01 wp04 Intermediate Casing r = 1C114, 24 ti CPA_Cao-dinate Converter3 From: —To: Datum: (NAD27 -I Region: (alaska .I Datum: NAD27 w Region: 'alaska C Latitude/Longitude 'Decimal Degrees — C Latitude/Longitude 'Decimal Degrees C UTM Zone:( (— South C' UTM Zone:'True E South State Plane Zone:'4 j Units: 1us-ft _1 C State Plane Zone:'True . Units:jus-ft J C 1 egal De-:cription 11'16.D27 only C.;' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1522720.89 Township: X010 N . Range: 1009 1E J Y: 15937593.64 Meridian: rU -I Saction:rl0 1FNL jj 1744.35599 'FEL . 11842.4983 Transform 1 Quit Help r ORIGINAL • • 2E-01 wp04 TD CPA'Coordinate Conve o �n ~ From: — To: Datum: 'NAD27 .1 Region: 'alaska .i Datum: NAD 27 H Region: lalaska .J i C LatitudelLongitude 'Decimal Degrees J C LatitudelLongitude 'Decimal Degrees J C UTM Zone:' r South f UTM Zone:ITrue 1— South ( State Plane Zone:14 =.1 Units:Ius-ft j r- State Plane Zone: True . Units: us-ft C Legal Description-INAD27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description -- X: 1522494.88 Township: IN ".• Range: 1009 E . Y: 15931772.81 Meridian: jU Section:115 FNL . 11285.0670 FEL 2095.6451 • Transform Quit Help s . ORIGINAL 2E-01 Drilling Risks Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg.Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 and 2F-19 as they become available and adjust the mud weight accordingly.Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Abnormal Reservoir Pressure Moderate Reservoir pore pressure is estimated at 10.0 ppg.But there is small chance of over pressured pay zone due to the offset well in the neighbor block is 11.0 ppg.Re- estimate the formation pressure based on results from shut in bottom hole pressures taken at near by wells 2F- 11 Land 2F-19 as they become available and adjust the RI I n t� L Prepared by Lindsey Hunter • • mud weight accordingly.Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology, add LCM. Use GKA LC decision tree. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Control trip speeds,monitor proper hole fill while tripping,good hole cleaning.Pump or back ream out if necessary. I1 N L Prepared by Lindsey Hunter .2E-01 (Wp 04) ! IV Grass Roots Horizontal A-Sand Producer ConocoPhillips Proposed Wellbore Schematic q'GAMERON 4-W tree,top joint is 4-Va"12.6#IBTM,crossed over(for frac equipment) Last Edited: I Existing Conductor: Hunter-5/13/14 16"62.6#H-40 Drilplex \` —110' MD/110'TVD 9.3 ppg 3'A"Camco DS Nipple 2.875" x'MD/XTVD 13-1/2"Surface Hole Cameo 3-'/"x 1-%" MMG Mandrel @ x' MD/x'TVD Base West Sak:4,811'MD/3,220'TVD Surface Casing 10-3/4"45.5#L-80 Hydril 563 4,811' MD/3,220'TVD @ 65° LSND xx PPG Tubing: 3-W 9.3#L-80 EUE8RD Camco 3-%"x 1-%" 1/1 MMG Mandrel @ x' MD he TVD 9-7/8" Intermediate Hole Estimated top of cement @+1-10,918'MD I Cameo 3- "x1-r" Intermediate Casing: Set in A5 GX TVD 7-5/8" @ x' MD7-5/8"29.7#L-80 Hydril 563 Surface to 11,436'MD/5,950'TVD @72° 7-5/8"39#TN-110SS Hydril 563 Profile and Sliding Sleeve - 11,436' MD/5,950'TVD to 12,436' MD/ for Jet Pump 6,152'TVD @ 85° Downhole Pressure Gauge 3-%"x 7-5/8",Premier Packer 11,590'MD Top Kuparuk C:11,918'MD/6,074'TVD Top Kuparuk A5: 12,345'MD 6,143'TVD WBM 4-%"Orange Xx PPG Peel shoe 3%'Camco XN Nipple 1.11 2.813"set at 74° . •y (Drop Ba: Drillable ll System)Sleeverac iC . iC oe 7-5/8",ZXP Liner Top Packer x'MD 7-5/8"x 4-%"Baker Flex Lock Liner hanger Pre-pert pups w/RS Nipple, 12,236'MD TD:18,266 MD/6,280'TVD Production Liner: 6-1/2" Production Hole 4-1/2" 12.6#L-80 Hydril 563 18,266' MD/6,280'TVD @ 88° ORIGINAL • • ConocoPhillips Alaska, Inc. yV Post Office Box 100360 RECEIVED v C LVED Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 JUN 0 3 2014 May 29,2014 AOGCC Alaska Oil and Gas Conservation Commission �"1 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2E-01,A Kuparuk A5 Sand Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2E pad. The expected spud date for this well is August 1st,2014. It is planned to use Rig Doyon 141. I 2E-01 is planned to be a horizontal Kuparuk A5 sand producer. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-4,816'MD/3,225'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 12,440'MD/6,157'TVD. The production hole will be drilled with 6-1/2"bit and run 4-1/2"liner to+/- 18,271'MD/6,285'TVD. The production lateral will be fractured using drillable fracture sleeves(drop ball system)and swell packers. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). t PER E F 1-1 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. "' K 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Callahan at 263-4180 (Mike.Callahan(&,ConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager SUPERSEDED • • Application for Permit to Drill Document Kuparuk Well 2E-01 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2E-01 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each ohjecnce for,nation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the stat,plane coordinate.'vs m for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4775'FNL, 5120'FEL, Sec 36, T 11N,R009E,UM NGS Coordinates RKB Elevation 131' AMSL Northings: 5,944,147.30' Eastings: 529,972.35' Pad Elevation 106'AMSL Location at Top of 654'FNL, 1831' FEL, Sec 10,T1ON,R009E,UM Productive Interval (Kuparuk A5 Sand) NGS Coordinates Measured Depth, RKB: 12,345' Northings: 5,937,683.78' Eastings:522,731.92' Total Vertical Depth, RKB: 6,143' Total Vertical Depth, SS: 6,009' Location at Total Depth 1285' FNL, 2096' FEL, Sec 15,T1ON,R009E,UM NGS Coordinates Measured Depth, RKB: 18,266' Northings: 5,931,772.81' Eastings: 522,494.88' Total Vertical Depth, RKB: 6,280' Total Vertical Depth, SS: 6,146' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. • The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each ofthe ollowing items,except for an item already on file with the commission and identified in the application: SUP $EDD (3)a diagram and description of the blowout prevention equipment P as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. ORIGINAL • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 2E-01 is calculated using an estimated ,/maximum reservoir pressure of 3,800 psi (11.9 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A5 sand at 6,143' TVD (WP04): A Sand Estimated. BHP = 3,800 psiUP _ * -- A Sand estimated depth(WP04) = 6,143' TVD - `- Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 614 psi (6,143' TVD * 0-.10 psilft) MPSP=BHP—gas column =3,186 psi (3,800 psi—614 psi) (B)data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (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; See attached 2E-01 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests.as required under 20 AAC 25.030(f); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) ���� t(lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/ 106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 4,788 Surf 4,816/3,225 1,755 sx ALC Lead 11.02 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 11,413 Surf 11,436/5,950 Continued from below 563 TN Hydril 412 sx Class G at 15.8 ppg w/TOC at 7-5/8 9-7/8 39 110 563 1,000 11,436/5,950 12,436/6,152) 10,918'MD 4 1/2 6-1/2 12.6 L-80 Hydril 6 031 11,615/6,000 18,271/6,285 Drillable Frac Sleeve(ball drop system) 563 with swell packers ORIGINAL • • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.5- 11.5 10.6- 11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. ORIGINAL I Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. it alpett -------gym ORIGINAL • • 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-4,811' MD/3,220' TVD as per directional plan (wp04). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top jo . 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's t 3000 psi annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform formation integrity test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 10,695'MD/5,666' TVD,back ream to the surface shoe at 4,811' MD ensuring a clean hole(this will allow pt he shales quickly,reducing exposure time). 9. RIH to top of HRZ and directionally drill to 12,345'MD/6,143' TVD, landing in the Kuparuk A5 sand. Wellsite geologist will call intermediate TD. Circulate and rotate until 1`ia'keis are clean. Short trip to top of shales at 10,695'MD on elevators,if no tight spots encountered continue to POOH. (If tight spots are encountered,back ream through only tight areas to top of HRZ,run back to bottom and circulate bottoms up.) 10. POOH on elevators. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from TD at 12,436'MD to surface. 13. Pump cement job as per Schlumberger proposal,top of cement to be 10,918' MD(500' MD above top of the Kuparuk C sands). 14. Set slips and install wellhead x 7-5/8"packoff and test to 3500 psi. 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,stethoscope,periscope,/ microscope,and neutron density) ,004.. t: 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation intitst to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 20. Directionally drill 6-1/2"hole geosteering though the Kuparuk A5 sand to TD 18,266' MD as per directional plan(wp04). 21. Circulate hole clean and POOH. 22. Lay down Production BHA. 23. PU and run 4-1/2", 12.6#,Hydril 563 liner with drillable frac sleeves(ball drop system). The top of liner will be placed at 12,236'MD,allowing for 200' of overlap in the 7-5/8"casing. 24. Set liner hanger. Slackoff and set liner top packer. ORIGINAL t • 25. Monitor well for flow for 15 minutes 26. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 27. Flow check well for 30 minutes to run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. s , ; 29. Freeze protect well with diesel and install BPV. rf8Q) 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Y ` Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well(1R- 18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. 1 • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regardinwaste classification. (659-7212). Attachments: Attachment 1 Directional Plan =— :> Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL • • 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. • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: KIR() QE -01 PTD: 02)Li a 7_5.' Development —Service Exploratory Stratigraphic Test —Non-Conventional FIELD: '4QUI( ? i .T POOL: kl,,p Lc iii.-,r 0 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo gg g in also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 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. 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J N •N 0 co O c W oI•E ca co a) 0 ; 0 Q coY 0 H Q a w (.9 a • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT MUDLOGGING DATA 2E-01 Provided by: Approved by: Phil Bottrell Compiled by: Allen Odegaard J a m e s A d a m s Distribution: 09/15/2014 Date: 09/08/2014 2E-02 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................5 3.1 Lithostratigraphy .............................................................................................................................5 3.2 Mudlog Summary............................................................................................................................6 3.3 Connection Gases ........................................................................................................................20 3.4 Trip (Wiper) Gases........................................................................................................................20 3.5 Gas Peaks & Associated Mud Data..............................................................................................21 3.6 Sampling Program / Sample Dispatch..........................................................................................22 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................23 4.1 Pore Pressure Gradient Evaluation ..............................................................................................23 4.2 Quantitative Methods....................................................................................................................24 5 DRILLING DATA..................................................................................................................................25 5.1 Survey Data..................................................................................................................................25 5.2 Bit Record.....................................................................................................................................29 5.3 Mud Record ..................................................................................................................................30 6 SHOW REPORTS ...............................................................................................................................31 7 DAILY REPORTS ................................................................................................................................33 Enclosures 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD 2E-02 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator and Gas Trap (mounted in mud return trough) Flame ionization total gas and chromatography. 2 Hrs Note: Chromatograph was down from 5,000’ to 5,189’ Block Height/Bit depth TOTCO WITS Feed 0 Hook Load / Weight on bit TOTCO WITS Feed 0 Mud Flow In Derived from Pump Rates and Pump Output 0 Mud Flow Out TOTCO WITS Feed 0 Mudlogging unit computer system HP Compaq Pentium 4 (x3: DML, Rigwatch, and Sample Catcher station) 3 days TOTCO & Rigwatch had communication problems for the better part of 3 days Pit Volumes, Pit Gain/Loss TOTCO WITS Feed 0 Pump Pressure TOTCO WITS Feed 0 Pump stroke counters TOTCO WITS Feed 0 Rate of penetration TOTCO WITS Feed 0 RPM TOTCO WITS Feed 0 Torque TOTCO WITS Feed 0 Data delivered as thousands of ft-lbs in integer format Crew Unit Type : Arctic Unit Number : ML32 Mudloggers Years *1 Days *2 Sample Catchers Years *1 Days *2 Technician Days Barry Sylvester 5 7 Ben Calo 1 12 Travis Smith 1 James Adams 2 12 Jarred McCleskey 1 12 Allen Odegaard 17 6 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down 2E-02 3 2 WELL DETAILS 2.1 Well Summary The 2E-01 is an injection well on the 2E Pad. Well: 2E-01 API Index #: 50-029-23517-00 Field: Prudhoe Bay Surface Co-Ordinates: T. 11 N, R009E, UE. Sec. 36, Umiat Meridian 4755’ FNL, 5120’ FEL Borough: North Slope Primary Target Depth: — State: Alaska Total Depth: 12570’ MD/6161’ TVD Rig Name / Type: Doyon #141 Arctic Triple Suspension Date: N/A Primary Target: Injection Well Ground Elevation: 105.1’ AMSL Spud Date: 08/24/2014 RT Elevation: 132.3’ AMSL Completion Date: (not available)* TD Date: 09/05/2014 Completion Status: 7 5/8” Casing* Secondary Target: Depth: — Classification: Injection TD Formation: A5 Days Drilling: 5 * Mudloggers released from wellsite prior to completion run 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD TVDSS TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVDSS (ft) LOT (ppg) Int. 12,570’ 6,161’ A5 10.2 83.36 7 5/8” — * Mudloggers released from wellsite prior to completion run Additional Comments: Production hole 61/2”, 41/2’ liner 2E-02 4 2.3 Daily Activity Summary 08/29/2014 Canrig personnel on site for unit ML032 rig up. 08/30/2014 Continued rig up; mount gas trap, run umbilical and poly flow lines. 08/31/2014 Continued rig up; install TOTCO PC. Test BOP—No test. Fix BOP, retest. 09/01/2014 Load BHA, RIH, drill out cement F/4851’. Drill new hole to 4970’. 09/02/2014 Drilled ahead from 4970’ to 7248’. 09/03/2014 Drilled ahead from drilling from 7248’ MD to 9747’ MD. 09/04/2014 Drilled ahead from drilling from 9747’ MD to 11876’ MD. 09/05/2014 Drilled ahead from drilling from 11876’ MD to 12570’ MD. TD @ 12570’. Pump OOH From 12570’ MD to 9752’ MD. 09/06/2014 POOH F/9843’ T/4935’ MD. Cont POOH on elevators to 760’ MD. Monitor well. 09/07/2014 Rig up casing tools, RIH with 75/8” casing T 8718’ MD. 09/08/2014 Finish running casing to bottom; circulate & condition well; pump cement. 09/09/2014 Rig down ML032. 2E-02 5 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops provided by the Waters Petroleum Geologist. PROGNOSED LWD PICK HORIZON MD (ft) SSTVD (ft) MD (ft) SSTVD (ft) Base W Sak 4,059' -3,087 4,742’ -3,039’ Top HRZ (K-2 Marker) 10,636’ -5,512 10,732’ -5,543’ U Kalubik (Base HRZ) 11,170’ -5,722’ 11,277’ -5,767’ L Kalubik (K-1 Marker) 11,530’ -5,841’ 11,637’ -5,862’ C (Top C4) 11,917’ -5,940’ 12,132’ -5,969’ B1 11,955’ -5,948’ 12,139’ -5,971’ A6 12,182’ -5,987’ 12,392’ -6,013’ A5 12,343’ -6,009’ 12,552’ -6,028’ 2E-02 6 3.2 Mudlog Summary Base W Sak (base of casing) to Top HRZ (4742’ MD to 10732’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 691 1.7 154.7 463 51 62.3 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9465 265.24 28863.883 2650.069 1098.016 418.525 0 213.045 178.100 9664 270.104 22295.530 1143.181 515.144 150.123 0 99.105 153.051 10482 516. 15557.421 2013.520 857.623 240.796 42.730 224.733 112.158 10727 499 13914.598 1886.383 918.525 271.579 426.798 188.918 137.546 Individual sample descriptions are as follows: Claystone (5000'-5050') = light gray to light gray with brownish hues, medium gray; curdy to pasty consistency; moderately cohesive; malleable tenacity; earthy fracture; dull earthy luster; silty to occasionally gritty texture; common black lithic fragments; trace very fine to fine grain orange lithics; occasional bluish gray to pale grayish blue green glauconite; no visible structures; no oil indicators. Siltstone (5050'-5100') = medium gray to medium dark gray; mushy to pasty consistency; moderately cohesive; slight adhesive; malleable tenacity; earthy fracture; dull, earthy luster; texture ranges from silty to gritty, occasionally clayey; no visible structures; weak reaction to HCl; no oil indicators. Claystone (5110'-5150') = light gray to light to light gray with brownish hues; pasty and lumpy consistency; very to moderately cohesive; moderately adhesive when probed; dull to earthy luster; silty to gritty texture; grading to siltstone; common very fine to fine grained black lithic fragments; trace orange and greenish gray lithics; no oil indicators. Siltstone (5160'-5220') = light gray to medium gray with greenish hues; pasty consistency; moderately cohesive; poor adhesive qualities; dull to earthy luster repetitive grading to clayey siltstone; increasing silt and decreasing clay with depth; dominantly silty with occasional clayey and gritty textures; variable reworked sand and accessory minerals; no visible structures; no oil indicators. Claystone (5220'-5270') = light gray to medium light gray with occasional brownish hues; pasty to occasionally curdy consistency; moderately cohesive; slightly adhesive; dull to earthy luster with an occasional waxy appearance; texture ranges from clayey to silty and slightly gritty; common black lithic fragments with occasional pale orange and light bluish gray pieces; common bluish gray glauconite; no visible structures; no oil indicators. Siltstone (5280'-5330') = medium gray to light gray with greenish hues; very soft to friable; moderately cohesive; slight adhesive when probed; dull to earthy luster, waxy in part; variable silty to gritty texture; generally silty and clayey with occasional gritty and silty pieces; scattered brittle siltstone; reddish brown to dusky brown; thinly laminated; no oil indicators noted. Claystone (5340'-5380') = medium brown, dark brown and dark brown with grayish hues; mushy consistency; crumbly; irregular to earthy fracture; amorphous cuttings habit; earthy to dull luster; clayey texture with silty to gritty inter-beds; inter-bedded with clayey siltstones and very thin very fine grain sands; no visible fluorescence in the sample. 2E-02 7 Siltstone (5390'-5440') = medium gray to medium dark gray with greenish hues; pasty consistency; poorly adhesive; slightly to moderately adhesive; dull to earthy luster; variable texture, ranging from clayey to slightly gritty; variable sand and accessory mineral grains in the matrix; no visible structures; extremely weak reaction to HCl; no fluorescence noted in the sample. Sand (5175'-5245') = translucent to clear, with some light gray to white hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper very fine to upper fine grain sand; well to moderately sorted throughout; well rounded to sub-rounded, with some sub-angular to angular; moderate to high sphericity; very thin sand lenses inter-bedded with thicker beds of silty claystones and clayey siltstones; no visible sample fluorescence was observed. Siltstone (5550'-5600') = medium gray to light gray; pasty consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to gritty texture; no structure visible; slight reaction to HCl; trace opaque and translucent quartz grains; fine to medium grained; trace brown lithic fragments; scattered mineral grain fluorescence; no other petroleum indicators. Sand (5600'-5650') = translucent to clear; predominantly quartz; medium to fine, moderately to well sorted, rounded to sub-rounded, moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; scattered mineral grain fluorescence; no other petroleum indicators. Claystone (5650'-5700') = light gray to medium light gray, to medium gray with brownish gray hues; clumpy consistency; moderately cohesive; slightly adhesive; hydrophilic; dull to earthy luster; dominantly silty to gritty texture with common reworked very fine grained sand; silty appearance in some clayey pieces; no visible structures, very weak reaction with HCl; no cut. Siltstone (5700'-5750') = medium gray to dark gray; pasty consistency; malleable; earthy fracture; amorphous cuttings habit; dull to earthy luster; silty to gritty texture; no visible structure; trace sand; trace dark to black lithic fragments; slight reaction to HCl; slight mineral grain fluorescence; no other petroleum indicators. Sand (5750'-5800') = translucent to clear; predominantly quartz; medium to fine; moderately to well sorted; rounded to sub-rounded; moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; trace tuff; scattered mineral grain fluorescence; no cut. Claystone (5800'-5850') = light gray to medium light gray, to medium gray with brownish gray hues; clumpy consistency moderately cohesive; slightly adhesive hydrophilic; dull to earthy luster; dominantly silty to gritty texture with common reworked very fine grained sand; silty appearance in some clayey pieces; no visible structures; very weak reaction with HCl; no cut. Siltstone (5850'-5900') = medium gray to dark gray; pasty consistency; malleable; earthy fracture; amorphous cuttings habit; dull to earthy luster; silty to gritty texture; no visible structure; trace sand; trace dark to black lithic fragments; slight reaction to HCl; slight mineral grain fluorescence; no other petroleum indicators. Sand (5900'-5950') = translucent to clear; predominantly quartz; medium to fine, moderately to well sorted; rounded to sub-rounded; moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; trace ash; scattered mineral grain fluorescence; no cut. Claystone (5950'-6000') = light gray to medium gray, clumpy; moderately to slightly cohesive; dull to earthy luster; silty, silty to gritty; inter- bedded with very fine grained sand; no visible structure; weak reaction with HCl scattered mineral grain fluorescence; no other petroleum indicators. 2E-02 8 Sandstone/siltstone (6000'-6080') = clear, light to medium gray, medium gray with brownish hues; disaggregated to soft cuttings, commonly lumpy masses of disaggregated silt with variable percentages of loose sand; sand is very fine to upper fine grained with trace lower medium grains; dominantly angular to sub-angular; white, clear and translucent quartz; common medium to dark gray lithics; micro-crystalline pyrite disseminated throughout; trace possible shell fragments; sample is very slightly calcareous; no visible oil indicators. Siltstone (6080'-6130') = light gray to medium gray with occasional brownish hues; pasty consistency; moderately cohesive, poor adhesion; dull to earthy luster; thin silty claystone laminae; grading to silty claystone; clay content increasing with depth; variable gritty texture due to reworked sand and accessory minerals; no visible structure no reaction to HCl. Claystone (6140'-6200') = light gray to medium light gray, medium gray with brownish hues; curdy to pasty; very cohesive; slightly adhesive; earthy to slightly waxy luster; clayey to silty texture, occasionally gritty; common black lithic fragments; occasional pale orange lithics and pale bluish green glauconite; no visible structures; no visible oil indicators. Siltstone (6190'-6280') = medium gray to light gray, medium gray with brownish hues; dominantly soft to easily friable cuttings; cuttings are generally rework masses of clayey siltstone and silty claystone with reworked sand and accessory minerals mixed in; moderately cohesive; slightly adhesive when probed; dominantly dull to earthy luster, waxy to occasionally vitreous in part; clayey to silty texture varies widely due to a mix of clay, silt, reworked sand and accessory mineral grains worked into the mass; texture is generally silty to clayey with occasional gritty and silty pieces; scattered brittle silt- stone, reddish brown to dusky brown, occurring as thin laminations; no oil indicators were noted in the sample. Claystone (6290'-6340') = medium brown, dark brown, dark brown with grayish hues dominantly pasty, occasionally mushy; crumbly tenacity; earthy to irregular fracture; amorphous cuttings habit; dull to earthy luster; dominantly clayey texture, grading to silty and slightly gritty in part; thick bedding with inter bedded clayey siltstones and thinly laminated silty sands; no fluorescence was observed in sample. Siltstone (6350'-6390') = medium gray to medium dark gray with brownish hues; dominantly pasty consistency; slightly adhesive when probed; earthy to dull luster; variable texture due to reworked sand and accessory mineral grains; commonly silty and clayey to silty and gritty; no visible structure; no visible fluorescence or other oil indicators in the sample. Sand (6400'-6470') = translucent to clear, occasional light gray to white grains; upper very fine to upper fine grains; well to moderately sorted; sub-rounded to sub-angular with trace angular grains; moderate sphericity; dominantly grain supported matrix with weak clay cement where consolidated; dominantly quartz grains with scattered dark gray lithic fragments; occurs as thin lenses, inter-bedded with silty claystones and clayey siltstones; no fluorescence or other oil indicators noted in the sample. Claystone (6480'-6540') = light gray to medium light gray, to medium gray with brownish gray hues; clumpy consistency moderately cohesive; slightly adhesive when probed; hydrophilic; dull to earthy luster with occasional waxy appearance; dominantly silty to gritty texture with common reworked very fine grained sand; silty appearance in some clayey pieces; no visible structures in the sample; very weak reaction with HCl; no visible fluorescence or other oil indicators. Siltstone (6550'-6600') = medium gray to medium dark gray, medium gray with brownish hues; mushy consistency; moderately cohesive; slightly adhesive when probed; variable text, ranging from clayey to silty and silty to gritty; generally dull to earthy appearance with some waxy pieces; no visible structures; very weak reaction with HCl; no visible fluorescence or other oil indicators. Siltstone (6600'-6650') = medium gray to medium dark gray, medium gray with brownish hues; mushy consistency; moderately cohesive; slightly adhesive when probed; variable texture, ranging from clayey to 2E-02 9 silty and silty to gritty generally dull to earthy appearance with abundant tuft; no visible structures; moderate reaction with HCl; no mineral fluorescence; no other oil indicators. Siltstone (6650'-6700') = medium to dark gray; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; gritty - silty texture; no visible structure; trace sand; trace black lithic fragments; moderate mineral fluorescence; fast, opaque, white cut; pale yellow residual cut. Siltstone (6700'-6750') = medium to dark gray; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; gritty - silty texture; no visible structure; trace sand, fine to medium grained, sub-rounded to sub-angular; light brown lithic fragments; trace tuft; mineral fluorescence; moderate, slow, translucent white cut. Siltstone (6750'-6800') = medium gray to medium dark gray, medium gray with brownish hues; mushy consistency; moderately cohesive; slightly adhesive when probed; variable texture, ranging from clayey to silty; dull to earthy; abundant tuff; no visible structure; moderate to vigorous reaction with HCl; slight mineral grain fluorescence; no cut or other oil indicators. Siltstone (6800'-6850') = medium gray to medium dark gray, with dark yellowish hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; mod to vigorous reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (6850'-6900') = medium gray to medium dark gray, with dark yellowish hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; mod to vigorous reaction with HCl; slight mineral grain fluorescence; moderate, slow, translucent white cut. Siltstone (6900'-6950') = medium gray to medium dark gray, with dark yellowish hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; abundant quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (6950'-7000') = medium gray to medium dark gray, with dark yellowish hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; calcite fragments; some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7000'-7050') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; calcite fragments; some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7050'-7100') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; calcite fragments; some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7100'-7130') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; calcite fragments; some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7130'-7160') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; some quartz sand (10%); moderate reaction with HCl; slight mineral grain fluorescence; no cut. 2E-02 10 Siltstone (7160'-7200') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; some quartz sand (10%); moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7200'-7250') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; trace quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7250'-7300') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; some quartz sand (10%); moderate reaction with HCl; slight mineral grain fluorescence; white, opaque, slow, light cut. Siltstone (7300'-7350') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; trace tuff; trace calcite; some quartz sand (10%); moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7350'-7400') = medium gray to medium dark gray, with light olive gray hues; mushy consistency; malleable; earthy fracture; massive cuttings habit; earthy luster; silty to clayey texture; no visible structure; some tuff; trace calcite; some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Siltstone (7400'-7450') = medium gray to medium dark gray, with light olive gray hues; mushy consistency, malleable, earthy fracture, massive cuttings habit, earthy luster, silty to clayey texture, no visible structure; some tuft; trace calcite, some quartz sand; moderate reaction with HCl; slight mineral grain fluorescence; no cut. Claystone (7510-7560) = light to medium gray; clumpy consistency; moderately cohesive; moderately adhesive; dull to earthy luster; occasionally waxy appearance; hydrophilic; variable silty to gritty texture due to inter-bedded very fine to fine grained sand; silt and sand imbedded in sample; no visible structure present; sample quality fair; no visible fluorescence or cut in sample. Siltstone (7570'-7610') = medium to medium dark gray, dark gray with greenish hues; pasty to mushy consistency; poorly adhesive when probed; moderately cohesive; dull to earthy luster; silty to gritty texture; variable sand and accessory mineral content; no visible structure; slight reaction to HCl; no visible fluorescence or other oil indicators. Sand (7620'-7700') = translucent to transparent with occasional light gray and white grains; dominantly quartz grain sand matrix, with occasional salt and pepper appearance due to dark gray lithic fragments; very fine to lower fine grained; grading to silt in part; moderately to well sorted; rounded to sub-rounded, with occasional sub-angular grains; common frosting due to surface abrasion and other impact features; moderate to high sphericity; occurs as very thin sand lenses inter-bedded with relatively thick silty claystone and clayey siltstone; no visible fluorescence, cut or other oil indicators. Claystone (7710'-7760')= light to medium gray, light gray with brownish hues; curdy to clumpy consistency; moderately cohesive; slightly adhesive; hydrophilic earthy to occasionally waxy luster; variable texture, ranging from clayey to gritty; inter-bedded very fine to fine grain sand; silt and sand imbedded in sample; sample quality fair; no visible structure; weak reaction with HCl; no visible fluorescence or other oil indicators. 2E-02 11 Siltstone (7770'-7820') = medium to medium dark gray; pasty to mushy consistency; poorly adhesive when probed; moderately cohesive; dull to earthy luster with occasional waxy appearance; variable texture, ranging from silty to gritty; common very fine grain sand and other minerals in sample; weak reaction to HCl sample quality fair; no visible fluorescence or other oil indicators. Sand (7830'-7900') = translucent to transparent, occasionally light gray to white; dominantly quartz sand matrix with occasional salt and pepper due to dark colored lithic fragments; upper very fine to upper fine grained, grading to silt in part; moderately to well sorted; rounded to sub-rounded with occasional angular and sub-angular grain frosted appearance with common impact features; moderate to high sphericity; occurs as very thin sand lenses within relatively thick beds of silty claystone and clayey siltstone; trace white ash; no visible fluorescence or other oil indicators; sample quality fair. Siltstone (7910'-7970') = light gray to medium gray; pasty to mushy; low to moderately cohesive; poor adhesive when probed; dull to earthy luster; clayey laminae common; texture variable between clayey to slightly gritty; increasing silt and decreasing clay with depth; variable reworked sand and accessory mineral content; relatively thick bedding with claystone and thin sandstone lenses; no visible fluorescence or other oil indicators. Claystone (7980'-8030') = medium gray to medium dark gray, medium gray with greenish hues; pasty consistency, common reworked masses containing sand and other accessory minerals; moderately cohesive, poorly adhesive when probed; inter-bedded with clayey siltstone; variable clayey to gritty texture due to reworked sand content; very weak reaction to HCl; no visible fluorescence or other oil indicators. Sand (8040'-8100')= translucent to clear with occasional white to light gray grains; dominantly quartz grain sand matrix with occasional salt and pepper appearance due to abundant dark gray lithic fragments; very fine to upper fine grain sand with trace medium grains fair to moderate sorting; rounded to very well rounded with occasional angular and sub-angular grains; moderate sphericity; thinly bedded with relatively thick siltstones and sandy claystones; grain supported matrix with weak clay cement; non-calcareous; no visible fluorescence or other oil indicators. Siltstone (8110'-8160') = dark gray to medium dark gray, dark gray with greenish hues; pasty to mushy; slightly adhesive; moderately cohesive; dull to earthy luster with occasional waxy pieces; variable texture, ranging from silty to gritty with variable sand and accessory mineral content; no visible structures; sand content increasing with depth; no visible fluorescence or other oil indicators. Sand/Sandstone (8170'-8230') = clear to off white, white to light gray; common loose unconsolidated sand with friable fine grain sandstone with weak clay/ calcareous cement; poor to fair sorting; upper fine to upper medium grains; very well rounded to sub-rounded with trace angular and sub-angular grains; high to moderate sphericity; appears as thin bed sand and sandstones, inter-bedded with sandy siltstones and sandy claystones; no visible fluorescence or other oil indicators. Siltstone (8240'-8300') = medium gray to light gray, light gray with greenish hue fair sample quality; cuttings appear as reworked masses containing sand and accessory minerals; inter-bedded clayey siltstones and silty claystones; fair cohesiveness; poor adhesiveness when probed; pasty to mushy consistency; dull to earthy luster; variable texture ranging from sandy/clayey to silty/ gritty; no visible structures; trace mineral fluorescence; no cut or other oil indicators. Claystone (8310'-8360') = light gray to medium gray, medium gray with brownish hues; dominantly mushy consistency; moderately cohesive; slightly adhesive when probed; earthy to waxy luster; no visible structures; trace brown to black lithic fragments scattered throughout sample; trace micro-cyrstalline pyrite; no visible fluorescence or other oil indicators. 2E-02 12 Sand/Sandstone (8370'-8460') = clear to translucent with scattered off white to light gray grains; 90% quartz, 10% lithic fragments; fine to lower medium with rare upper medium grains; poor to fair sorting; sub- rounded to sub-angular moderate sphericity; unconsolidated to soft and easily friable; grain supported matrix with weak clay cement; quartz grains are clear to translucent, milky; slightly frosted with occasional impact features; conchoidal fracture on some grains; trace orange and yellow lithic fragments; common dark gray and brownish gray grains; occasional glauconite grains; trace micro-crystalline pyrite; non- calcareous; no visible fluorescence or other oil indicators. Siltstone (8470'-8530') = light gray to medium dark gray; mushy to pasty consistency; moderately cohesive; poor adhesion when probed; dull to earthy luster with occasional waxy pieces; variable texture, ranging from clayey siltstone to sandy siltstone; silt content appears to be increasing with depth, with decreasing clay content texture varies with the percentage of reworked sand and accessory minerals; no visible structures; no visible fluorescence or other oil indicators. Sand/Sandstone (8540'-8610') = clear to translucent, occasional off white to milky white, light to medium grey; dominantly quartz grain supported matrix where consolidated; common dark gray to black colored lithic fragments throughout sample; fine to lower medium grains with occasional upper medium pieces; poor to fair sort; well rounded to sub-rounded with scattered angular to sub-angular grains; moderate sphericity; inter-bedded loose unconsolidated sand with easily friable sandstones; variable weak clay/calc cement; sample quality fair to good; no visible fluorescence or other oil indicators. Siltstone (8620'-8670') = medium gray to medium dark gray with greenish hues; mushy consistency; moderately cohesive; slightly adhesive; dull to earthy luster variable clayey to gritty texture; common reworked sand and accessory minerals contributing to gritty textures; sand content increasing with depth; no visible structures; no visible fluorescence or other oil indicators. Sand/Sandstone (8680'-8750') = clear, translucent to white with scattered light gray grains; dominantly quartz grain; unconsolidated to easily friable; weak calcareous cement; upper fine to upper medium grain sandstone; moderate to poorly sorted; upper fine to upper medium grained sand; rounded to sub-rounded, occasional angular and sub-angular grains; moderate to high sphericity; relatively thick beds of sand and fine grained sandstones are inter-bedded with sandy claystones and sandy siltstones; no visible fluorescence or other oil indicators. Claystone (8760'-8810') = light gray to medium gray, medium gray with greenish hues; mushy consistency; moderately cohesive; slightly adhesive when probed; earthy luster with occasional waxy pieces; scattered brown to very dark gray splintery lithics; trace micro-crystalline pyrite; no visible structures; sample quality fair; no visible structures; no visible fluorescence or other oil indicators. Siltstone (8820'-8890') = light gray to medium gray; pasty to mushy consistency; moderately cohesive; slightly adhesive; cuttings are mechanically reworked globular masses containing sand and accessory minerals; texture varies with clay and sand content but is typically silty to gritty with some clayey cuttings; no visible structures; no visible fluorescence or other oil indicators. Siltstone (8900'-8950') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; adhesive to plastic; trace quartz sand; trace tuft; trace glauconite; no visible structure; no visible fluorescence or other oil indicators. Siltstone (8950'-9000') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; adhesive to plastic; 2E-02 13 trace quartz sand; trace tuft; trace glauconite; reactive with HCl; no visible structure; no visible fluorescence or other oil indicators. Siltstone (9000'-9050') = medium to dark gray; cohesive; stiff, brittle tenacity; planar fracture; scaly to tabular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; some tuff and calcite fragments; reactive to HCl; trace sandstone; no visible fluorescence or other petroleum indicators. Siltstone (9050'-9100') = medium to dark gray; cohesive; stiff, brittle tenacity; planar fracture; scaly to tabular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; some calcite fragments; reactive to HCl; trace sandstone; no visible fluorescence or other petroleum indicators. Siltstone (9100'-9150') = medium to dark gray with some clay; cohesive; stiff, brittle tenacity; scaly to tabular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; some calcite; very reactive to HCl; trace sandstone; no visible fluorescence or other petroleum indicators. Siltstone (9150'-9200') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; adhesive to plastic; trace quartz sand; trace tuft; trace glauconite; reactive with HCl; no visible structure; no visible fluorescence or other oil indicators. Siltstone (9200'-9250') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; adhesive to plastic; trace quartz sand; reactive with HCl; no visible structure; no visible fluorescence or other oil indicators. Siltstone (9250'-9300') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure; adhesive to plastic; trace quartz sand; reactive with HCl; no visible structure; no petroleum indicators. Siltstone (9300'-9350') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty no visible structure; adhesive; trace quartz sand; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (9350'-9400') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (9400'-9450') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (9450'-9500') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty; no visible structure; adhesive; trace quartz sand; trace tuff; trace shell fragments; trace calcite; reacts with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (9500'-9550') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty; no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (9550'-9600') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone and sand (9600'-9700') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty texture; no visible structure; adhesive; abundant sand - mostly quartz, some black grains; fine to medium grains; well to moderately sorted; sub-rounded to 2E-02 14 sub-angular with trace angular grains; moderate sphericity; trace black lithic fragments; trace light brown lithic fragments; trace glauconite; calcite fragments; reacts vigorously with HCl. Sand (9700'-9750')=translucent to clear; predominantly quartz; medium to fine; moderately to well sorted; rounded to sub-rounded; moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; trace tuft; scattered mineral grain fluorescence; no fluorescence or other petroleum indicators. Sand (9750'-9800')=translucent to clear; predominantly quartz; medium to fine; moderately to well sorted; rounded to sub-rounded; moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; trace tuft; scattered mineral grain fluorescence; no other fluorescence or other petroleum indicators. Sand (9800'-9850')=translucent to clear; predominantly quartz; medium to fine; moderately to well sorted; rounded to sub-rounded; moderate to high sphericity; some grains frosted; supported; trace brown lithic fragments; trace tuft; no fluorescence or other petroleum indicators. Siltstone and Sand (9850'-9900') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty texture; no visible structure; adhesive; abundant sand - mostly quartz, some black grains; fine to medium grains; well to moderately sorted; sub-rounded to sub-angular with trace angular grains; moderate sphericity; trace black lithic fragments; trace light brown lithic fragments; calcite fragments; trace tuff. Siltstone (9950'-10000') = light gray to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty; no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (10000'-10050') = light to medium gray; pasty to mushy; malleable; earthy fracture; nodular cuttings habit; dull to earthy luster; silty to gritty; no visible structure; adhesive; trace quartz sand; trace tuff; reactive with HCl; no visible structure; no fluorescence or other petroleum indicators. Siltstone (10050'-10100') = light to medium gray; malleable to crunchy; irregular to earthy fracture; massive cuttings; earthy luster; silty/gritty texture; moderate to well consolidated; 20% floating sand; dominantly quartz; black lithics; calcite; some sandstone; medium gray; lower medium to upper fine; grain support; trace claystone; platy cuttings; trace sulfides; HCl reaction. Siltstone/Sandstone (10100'-10150') = 60% siltstone; medium to dark gray; tough; irregular fracture; massive cuttings; earthy luster; silty to gritty texture; well indurated; 30% conglomeritic sandstone; medium gray; lower medium to upper fine; well sorted; sub-rounded to rounded; moderate sphericity; well indurated; matrix filled voids; trace claystone; platy cuttings; fairly indurated. Siltstone (10150'-10200') = light to medium gray; malleable to crunchy; irregular to earthy fracture; massive cuttings; earthy luster; silty/gritty texture; moderate induration; 20% floating sand; dominantly quartz; black lithics; calcite; some conglomeritic sandstone; medium gray; medium to fine; grain support; moderately indurated; well sorted; trace claystone; platy cuttings; fairly indurated. Siltstone (10200'-10290') = light to medium gray; crunchy; irregular to earthy fracture; angular cuttings; earthy to waxy luster; silty/gritty texture; moderately to well consolidated; 20% floating sand; dominantly quartz; black lithics; calcite; some sandstone; medium gray; lower medium to upper fine; grain support; trace claystone and tuff; trace glauconite. Carbonaceous Siltstone (10290'-10350') = light/dark gray to black siltstone and pale quartz/lithic sandstone; siltstone is crumbly to firm, brittle, planar/platy/ massive cuttings habit; silty to gritty texture, thin laminae; sand is very fine grained; well sorted; matrix supported; angular; grains composed of quartz, sedimentary lithics, with a calcareous cement; trace amounts of calcite; weak reaction with HCl; no hydrocarbon indicators. 2E-02 15 Carbonaceous Siltstone (10350'-10420') = light/dark gray to black siltstone; and pale quartz/lithic sandstone siltstone is crumbly to firm, brittle, planar/platy/ elongated cuttings habit; silty to gritty texture, thin laminae; sand is very fine grained; well sorted; matrix supported; angular; grains composed of quartz, sedimentary lithics, and pyrite with a calcareous cement; trace amounts of calcite; weak reaction with HCl no hydrocarbon indicators. Carbonaceous Siltstone (10420'-10480') = light/dark gray to black siltstone and pale quartz/lithic sandstone; siltstone is crumbly to firm, brittle, planar/platy/ elongated cuttings habit; silty to gritty texture, thin laminae; sand is very fine grained; well sorted; matrix supported; angular; grains composed of quartz, lithic fragments and pyrite with a calcareous cement; trace amounts of calcite; weak reaction with HCl no hydrocarbon indicators. Carbonaceous Siltstone (10480'-10520') = light/dark gray to black siltstone; siltstone is crumbly to firm, brittle, planar/platy/ elongated cuttings; silty to gritty texture, thin laminae; trace pyrite, calcite, shale present; moderate reaction to HCl; no oil indicators. Carbonaceous Siltstone (10520'-10570') = light/dark gray to black siltstone inter-bedded with pale calcareous, quartz/lithic fine sand; siltstone is crumbly to firm, brittle, planar/platy/and elongated cuttings; silty to gritty texture; thin laminae; trace pyrite; abundant calcite; medium reaction to HCl; no hydrocarbon indicators. Carbonaceous Siltstone (10550'-10640') = light/dark gray to black siltstone and pale quartz/lithic sandstone; siltstone is crumbly to firm, brittle; planar, platy, and elongated cuttings habit; silty to gritty texture, thin laminae; sand is very fine grained; well sorted; matrix supported; angular; grains composed of quartz, sedimentary lithics with calcareous cement; trace pyrite, calcite, and shale present; weak reaction to HCl; calcite mineral fluorescence; slow milky cut fluorescence. Top HRZ (K2-Marker) to U Kalubik (Base HRZ) (10732’ to 11277’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 197 43.4 145.7 549 48 337.7 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 — — — — — — — — — Individual sample descriptions are as follows: Carbonaceous Siltstone (10640'-10710') = light/dark gray to black siltstone with minor fissile shale; crumbly to firm, brittle; planar/platy/elongated cuttings, silty to gritty texture, thin laminae; calcite and pale white fine carbonate; trace amounts of pyrite; moderate reaction to HCl; strong fluorescence of carbonate sand, slow milky cut. Carbonaceous Siltstone (10710'-10780') = medium to medium dark gray; very dark gray with olive hues; very dark gray to grayish black; crumbly to firm, some brittle to hard; irregular to blocky to planar fracture; splintery to wedge-like cuttings habit; silty to occasional gritty texture; thinly laminated to thick structure; occasional carbonaceous laminae; trace to scattered soft white to yellowish gray devitrified ash; trace sub- rounded medium to coarse sand grains; no visible fluorescence. Carbonaceous Siltstone (10780'-10830') = light/dark gray to black siltstone; siltstone is crumbly to firm, brittle, planar/platy/elongated cuttings habit; silty to gritty texture, thin laminae; laminated and loose 2E-02 16 carbonate present along with pyrite and very fine sand; weak reaction to HCl; no hydrocarbon indicators. Carbonaceous Siltstone (10830'-10890') = light/dark gray to black siltstone with minor fissile gray shale present; siltstone is crumbly to firm, brittle, planar/platy/elongated cuttings habit; silty to gritty texture, thin laminae; laminated and loose carbonate present along with pyrite and very fine sand; slightly calcareous; no hydrocarbon indicators. Sandy Siltstone (10890'-10950') = light to medium gray siltstone with moderate amounts of loose sand and calcareously cemented sandstone; siltstone is crumbly to firm, brittle, planar/platy and elongated cuttings, silty to gritty texture, thin laminae; predominantly loose sand with some consolidated; trace pyrite and oxidized lithics; moderate reaction to HCl; no hydrocarbon indicators. Sandy Siltstone (10950'-11000) = light dark gray siltstone with abundant loose sand; siltstone is crumbly to firm, brittle, planar/platy cuttings habit, silty to gritty texture, thin laminae; laminae; sand is upper very fine grained and well sorted, angular to sub-angular to sub-rounded, quartz, calcite, and sedimentary lithics; moderate reaction to HCl; no oil indicators. Siltstone (11000'-11050') = light to medium gray siltstone with loose carbonate; siltstone is firm, brittle, planar/platy/blocky cuttings habit; silty to gritty texture, thin laminae; trace pyrite and partially silicified terrestrial plant matter; weak reaction HCl; no hydrocarbon indicators. Sandy Siltstone (11050'-11100') = light gray siltstone with abundant loose sand; siltstone is crumbly, brittle, planar/platy cuttings, gritty texture, thin laminae; sand is rather abundant but poorly cemented, quartz, carbonate and sedimentary lithics are present; moderate reaction to HCl; no hydrocarbon indicators. Sandy Siltstone (11100'-11140') = light to dark gray siltstone with abundant loose very fine sand and minor well cemented sandstone; siltstone is crumbly, planar to platy cuttings habit, silty texture, thin laminae; moderate reaction to HCl; no hydrocarbon indicators. Siltstone (11150'-11190') = medium to dark gray to black siltstone, sand, and shale; uneven to planar fracture, massive to platy cuttings habit, dull luster, gritty texture, thin laminae; trace calcareous, very fine grained, calcareous cemented sandstone present; weak reaction to HCl; fluorescence of calcite, slow milky cut. U Kalubik (Base HRZ) to L Kalubik (K-1 Marker) (11277’ to 11637’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 317.6 11.6 129.2 487 70 201.8 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 — — — — — — — — — Individual sample descriptions are as follows: Siltstone (11190'-11230') = medium gray to black siltstone; planar fracture, massive to platy cuttings habit, dull luster, gritty texture, thin laminae; trace calcite; calcareous sandstone, weak reaction to HCl; no hydrocarbon indicators. Siltstone (11230'-11280') = medium gray to black siltstone; planar fracture, massive to platy cuttings habit, dull luster, gritty texture, thin laminae; low amounts of calcite, sandstone, lithic fragments, and fissile shale; 2E-02 17 weak reaction to HCl; no hydrocarbon indicators. Siltstone (11280'-11320') = medium gray to black siltstone; planar fracture, massive to platy cuttings habit, dull luster, gritty texture, thin laminae; moderate calcite is present, trace pyrite and calcareous sandstone; weak reaction to hydrochloric acid; no hydrocarbon indicators. Siltstone (11320'-11380') = light blue, dark gray, and black siltstone; brittle to crumbly, platy to blocky cuttings, dull luster, gritty to silty texture, thin laminae; minor fissile shale, and pale sand; trace pyrite and calcite; moderate reaction to HCl; no hydrocarbon indicators. Carbonaceous Siltstone (11380'-11450') = medium to medium dark gray; very dark gray with olive hues; very dark gray to grayish black; crumbly to firm, some brittle to hard; irregular to blocky to planar fracture; splintery to wedge-like cuttings habit; silty to occasional gritty texture; thinly laminated to thick structure; occasional carbonaceous laminae; trace to scattered soft white to yellowish gray devitrified ash; trace sub- rounded medium to coarse sand grains; no visible fluorescence in sample. Carbonaceous Siltstone (11450'-11500') = medium to medium dark gray, very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; trace tuff; calcite fragments; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11500'-11550') = medium to medium dark gray, very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; trace tuff; calcite fragments; no mineral fluorescence or other petroleum indicators. L Kalubik (K-1 Marker) to C (Top C4) (11637’’ to 12132’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 355 3.7 116.1 157 9.4 72.3 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 — — — — — — — — — Individual sample descriptions are as follows: Carbonaceous Siltstone (11550'-11600') = medium dark gray to very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; trace tuff, calcite fragments; reacts to HCl; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11600'-11650') = medium dark gray to very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; trace tuff, calcite fragments; reacts to HCl; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11650'-11700') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; trace tuff; calcite fragments; no mineral fluorescence or other petroleum indicators. 2E-02 18 Carbonaceous Siltstone (11700'-11750') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; calcite fragments; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11750'-11800') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; calcite fragments; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11800'-11850') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; particle dominated - packstone; vigorous reaction with HCl; calcite fragments; trace quartz sand; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11850'-11900') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous reaction with HCl; calcite fragments; trace tuff; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (11900'-11950') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous reaction with HCl; calcite fragments; trace tuff; trace sand; no mineral fluorescence or other petroleum indicators. C (Top C4) to B1 (12132’ to 12139’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 127.4 1.7 80.6 403.7 115.7 269.7 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 — — — — — — — — — Individual sample descriptions are as follows: Carbonaceous Siltstone (11900'-11950') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous reaction with HCl; calcite fragments; trace tuff; trace sand; no mineral fluorescence or other petroleum indicators. B1 to A6 (12139’ to 12392’ MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 172.7 37.3 78.1 407.2 53 119.3 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 12140 407.19 68228.901 4395.343 2045.204 640.195 0 1097.997 668.033 Individual sample descriptions are as follows: Carbonaceous Siltstone (11950'-12000') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous 2E-02 19 reaction with HCl; calcite fragments; trace tuff; trace sand; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (12000'-12050') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous reaction with HCl; calcite fragments; trace tuff; trace sand; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (12050'-12100') = brown, medium dark gray -- very dark gray; brittle to crumbly; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with some laminae; vigorous reaction with HCl; calcite fragments; trace tuff; trace sand; no mineral fluorescence or other petroleum indicators. Carbonaceous Siltstone (12100'-12150') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; pale yellow slow cut, no mineral fluorescence. Sand (12150'-12200') = quartz and dark gray, medium grain, fairly sorted, sub-angular to sub-round, mod sphericity; some grains frosted, some quartz opaque; unconsolidated, calcite cement, grain supported; trace black and brown lithic fragments; abundant carbonaceous siltstone and claystone; no mineral fluorescence or other oil indicators. A6 to A5 (12392’ to 12552’ MD) to TD of Intimidate Hole (12,570’) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 203.9 5.2 48.6 40.7 18.0 133 Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 12564 410.69 15933.39 2559.239 1428.041 474.62 294.181 297.585 Individual sample descriptions are as follows: Sand (12200'-12250') = quartz and dark gray, medium grain, fairly sorted, sub-angular to sub-round, mod sphericity; some grains frosted, some quartz opaque; unconsolidated, calcite cement, grain supported; trace black and brown lithic fragments; abundant carbonaceous siltstone and claystone; no mineral fluorescence, fast pale yellow cut. Carbonaceous Siltstone (12250'-12300') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; gritty to granular; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; trace pyrite; trace glauconite; orange mineral fluorescence, fast pale yellow cut. Carbonaceous Siltstone (12300'-12350') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; trace pyrite; yellow orange mineral fluorescence, fast pale yellow transparent cut. Carbonaceous Siltstone (12350'-12400') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae; reaction with HCl; trace quartz and black sand and calcite fragments; trace pyrite; yellow orange mineral fluorescence, fast pale yellow transparent cut. 2E-02 20 Carbonaceous Siltstone (12400'-12450') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae, reaction with HCl trace quartz and black sand calcite fragments; trace pyrite; yellow orange mineral fluorescence, fast pale yellow transparent cut. Carbonaceous Siltstone (12400'-12450') = brown, medium dark gray-- very dark gray; brittle, platy to flaky cuttings habit, dull luster granular; unconsolidated thin structure with laminae, reaction with HCl; abundant quartz and black sand calcite fragments; trace pyrite; yellow mineral fluorescence; moderate white slow cut. Carbonaceous Siltstone (12450'-12500') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; trace pyrite; yellow mineral fluorescence; moderate white slow cut. Carbonaceous Siltstone (12500'-12570') = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; trace pyrite; yellow, bright, mineral fluorescence with a fast, transparent to white cut. 3.3 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG 12121’ MD 286 U 3.4 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) No trips were made 2E - 0 2 21 3. 5 G a s P e a k s & A s s o c i a t e d M u d D a t a De p t h (M D / T V D ) To t a l Ga s (u n i t s ) C1 (p p m ) C2 (p p m ) C3 (p p m ) iC 4 (p p m ) nC 4 (p p m ) iC 5 (p p m ) nC 5 (p p m ) Mu d W e i g h t s w i t h a s s o c i a t e d s h o w (p p g ) Mud Temp. Out (°F) 9, 4 6 5 ’ / 5, 1 6 0 ’ 26 5 . 2 4 2 8 8 6 3 . 8 8 3 2 6 5 0 . 0 6 9 1 0 9 8 . 0 1 6 4 1 8 . 5 2 5 0 2 1 3 . 0 4 5 1 7 8 . 1 0 0 9 . 8 9 . 8 0 . 0 1 0 3 9, 6 6 4 ’ / 5, 2 4 2 ’ 27 0 . 1 0 4 2 2 2 9 5 . 5 3 0 1 1 4 3 . 1 8 1 5 1 5 . 1 4 4 1 5 0 . 1 2 3 0 9 9 . 1 0 5 1 5 3 . 0 5 1 9 . 8 9 . 8 0 . 0 1 0 3 10 , 4 8 2 ’ / 5, 5 7 4 ’ 51 6 . 0 1 5 5 5 7 . 4 2 1 2 0 1 3 . 5 2 0 8 5 7 . 6 2 3 2 4 0 . 7 9 6 4 2 . 7 3 0 2 2 4 . 7 3 3 1 1 2 . 1 5 8 9 . 8 9 . 8 0 . 0 1 0 2 10 , 7 2 7 ’ / 5, 6 7 6 ’ 49 9 . 0 1 3 9 1 4 . 5 9 8 1 8 8 6 . 3 8 3 9 1 8 . 5 2 5 2 7 1 . 5 7 9 4 2 6 . 7 9 8 1 8 8 . 9 1 8 1 3 7 . 5 4 6 1 0 . 1 1 0 . 1 0 . 0 1 0 8 12 , 1 4 0 ’ / 6, 1 0 3 ’ 40 7 . 1 9 6 8 2 2 8 . 9 0 1 4 3 9 5 . 3 4 3 2 0 4 5 . 2 0 4 6 4 0 . 1 9 5 0 1 0 9 7 . 9 9 7 6 6 8 . 0 3 3 1 0 . 2 1 0 . 2 0 . 0 1 1 2 12 , 5 6 4 ’ / 6, 1 6 1 ’ 41 0 . 6 9 1 5 9 3 3 . 3 9 2 5 5 9 . 2 3 9 1 4 2 8 . 0 4 1 4 7 4 . 6 2 0 2 9 4 . 1 8 1 2 9 7 . 5 8 5 1 0 . 2 1 0 . 2 0 . 0 1 1 4 2E-02 22 3.6 Sampling Program / Sample Dispatch Samples were collected at 50’ intervals for mudlogging purposes only. No samples were bagged/boxed on this well. 2E - 0 2 23 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Ba s e d o n a r e g i o n a l p r e s s u r e g r a d i e n t , t h e p o r e p r e s s u r e g r a d i e n t ( P P G ) i s e s t i m a t e d t o b e 0 . 4 5 5 p s i / f t , o r 8 . 8 p p g i n t h e t a r g et sand. 4. 1 P o r e P r e s s u r e G r a d i e n t E v a l u a t i o n In t e r v a l T o p s P o r e P r e s s u r e ( E M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) TV D (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators Ba s e W S a k — — 4 , 7 4 2 ’ 3 , 1 7 2 ’ - 3 , 0 3 9 ’ — — — — To p H R Z ( K - 2 Ma r k e r ) Sl t s t 6 0 % Cl s t 2 0 % , Sn d s t 1 0 % , Sd 1 0 % 10 , 7 3 2 ’ 5 , 6 7 8 ’ - 5 , 5 4 3 ’ 9 . 7 1 0 . 4 e v e n B G , E C D U K a l u b i k ( B a s e HR Z ) Sl t s t 7 0 % Cl s t 1 0 % , Sn d s t 1 0 % , Sh 1 0 % 11 , 2 7 7 ’ 5 , 8 9 8 ’ - 5 , 7 6 7 ’ 1 0 . 9 1 0 . 5 e v e n B G , E C D L K a l u b i k ( K - 1 Ma r k e r ) Sl t s t 8 0 % Sh 1 0 % , Cl s t 5 % , Sd 5 % 11 , 6 3 7 ’ 5 , 9 9 5 ’ - 5 , 8 6 2 ’ 1 0 . 7 1 0 . 8 e v e n B G , E C D C ( T o p C 4 ) S l t s t 7 0 % Cl s t 1 0 % , Sd 1 0 % , Sh 1 0 % 12 , 1 3 2 ’ 6 , 1 0 2 ’ - 5 , 9 6 9 ’ 1 0 . 9 1 1 . 1 e v e n B G , E C D B1 S l t s t 6 0 % Sd 2 0 % , Cl s t 1 0 % , Sh 1 0 % 12 , 1 3 9 ’ 6 , 1 0 3 ’ - 5 , 9 7 1 ’ 1 0 . 7 1 1 . 1 e v e n B G , E C D A6 S l t s t 5 0 % Sd 4 0 % , Cl s t 5 % , Sh 5 % 12 , 3 9 2 ’ 6 , 1 4 3 ’ - 6 , 0 1 3 ’ 1 0 . 7 1 1 . 1 e v e n B G , E C D A5 S l t s t 8 0 % Sn d s t 2 0 % , Sh 1 0 % , Cl s t 1 0 % 12 , 5 5 2 ’ 6 , 1 6 0 ’ - 6 , 0 2 8 ’ 1 0 . 7 1 1 . 1 e v e n B G , E C D NO T E : S d = S a n d , C l s t = C l a y s t o n e / C l a y , S l t s t = S i l t s t o n e , S n d s t = Sa n d s t o n e , S h = S h a l e , C s C o n g l o m e r a t e S a n d , C g = C o n g l o m e r a te 2E - 0 2 24 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s re l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u l a t i n g d e n s i t y ( E CD), including in c r e a s e s i n b a c k g r o u n d g a s ( B G ) , a p p e a r a n c e a n d t r e n d s o f c o n n e c t i o n ga s ( C G ) , a n d m a g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( WG). Regional po r e p r e s s u r e t r e n d s f r o m s o n i c d a t a , p r o v i d e d b y C o n o c o P h i l l i p s , an d s u r f a c e m a n i f e s t a t i o n s o f h o l e c o n d i t i o n s w e r e a l s o c o n s i dered. As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u l a p r ov i d e d b y E p o c h , a n d t h e n m o d i f i e d us i n g t h e i n d i c a t o r s d e s c r i b e d above, and DXC and re s i s t i v i t y ( R E S ) d a t a . T h e f o r m u l a u s e s D X , E C D , a n d B G a s m e a s u r e d b y t o t a l d i t c h g a s : PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , a n d T L G S U m u s t b e differentiated fr o m s h o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t o n r e l i a b l e D X d a t a . H o w e v e r , t h e f o r m u l a p r o v e d u s e f ul in helping fo r m u l a t e a P P G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d a t a , w i t h d a t a p o i n t s i n s h a l e i n t e r v a l s . 2E-02 25 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 27.20 0.00 0.00 27.20 0.00 0.00 0.00 0.00 82.30 0.12 346.37 82.30 -0.06 0.06 -0.01 0.22 169.97 0.17 13.79 169.97 -0.27 0.27 0.00 0.10 267.63 0.29 17.67 267.63 -0.65 0.65 0.11 0.12 360.76 1.24 230.29 360.75 -0.23 0.23 -0.60 1.60 452.70 1.88 226.15 452.66 1.45 -1.45 -2.45 0.71 544.39 2.83 225.41 544.27 4.08 -4.08 -5.15 1.04 637.42 5.44 223.67 637.05 8.89 -8.89 -9.83 2.81 729.79 7.68 229.83 728.81 16.04 -16.04 -17.57 2.54 819.52 9.86 231.62 817.49 24.67 -24.67 -28.18 2.45 912.27 12.11 231.93 908.53 35.60 -35.60 -42.06 2.43 968.94 12.65 232.03 963.88 43.09 -43.09 -51.63 0.95 1,061.15 13.77 231.80 1,053.65 56.09 -56.09 -68.22 1.22 1,155.70 16.06 231.53 1,145.01 71.18 -71.18 -87.30 2.42 1,245.72 17.37 231.58 1,231.22 87.28 -87.28 -107.58 1.46 1,339.70 19.81 230.13 1,320.29 106.21 -106.21 -130.80 2.64 1,432.92 21.09 230.37 1,407.64 127.03 -127.03 -155.84 1.38 1,524.42 21.03 230.51 1,493.03 147.98 -147.98 -181.19 0.09 1,617.89 24.73 229.09 1,579.13 171.45 -171.45 -208.92 4.00 1,710.50 27.43 228.92 1,662.30 198.16 -198.16 -239.64 2.92 1,803.00 29.65 228.87 1,743.55 227.21 -227.21 -272.94 2.40 1,895.81 33.32 229.39 1,822.69 258.92 -258.92 -309.59 3.97 1,988.11 36.46 231.39 1,898.39 292.54 -292.54 -350.28 3.62 2,081.00 40.84 233.55 1,970.92 327.83 -327.83 -396.30 4.93 2,172.88 43.86 233.38 2,038.82 364.67 -364.67 -446.03 3.29 2,266.07 48.03 233.43 2,103.60 404.59 -404.59 -499.79 4.47 2,358.72 51.49 233.04 2,163.44 446.92 -446.92 -556.43 3.75 2,451.27 53.55 232.27 2,219.76 491.47 -491.47 -614.81 2.32 2,542.00 56.53 231.27 2,271.74 537.49 -537.49 -673.21 3.41 2,634.73 59.15 231.16 2,321.09 586.66 -586.66 -734.40 2.83 2,727.57 62.83 230.94 2,366.11 637.70 -637.70 -797.53 3.97 2,819.76 64.69 231.70 2,406.87 689.37 -689.37 -862.08 2.15 2,913.00 64.99 229.96 2,446.51 742.67 -742.67 -927.50 1.72 3,005.29 65.43 228.99 2,485.21 797.11 -797.11 -991.19 1.07 3,095.53 66.12 228.56 2,522.24 851.35 -851.35 -1,053.08 0.88 3,189.54 67.82 228.01 2,559.01 908.92 -908.92 -1,117.66 1.89 3,281.46 67.82 228.08 2,593.72 965.82 -965.82 -1,180.96 0.07 2E-02 26 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 3,375.75 66.78 227.25 2,630.10 1,024.40 -1,024.40 -1,245.26 1.37 3,468.55 65.99 227.20 2,667.28 1,082.15 -1,082.15 -1,307.67 0.85 3,561.77 66.45 228.87 2,704.87 1,139.18 -1,139.18 -1,371.10 1.71 3,654.01 68.08 230.77 2,740.52 1,194.06 -1,194.06 -1,436.10 2.59 3,746.83 66.20 232.25 2,776.58 1,247.29 -1,247.29 -1,503.03 2.50 3,839.66 65.45 232.86 2,814.59 1,298.79 -1,298.79 -1,570.27 1.01 3,931.94 68.89 233.36 2,850.39 1,349.83 -1,349.83 -1,638.28 3.76 4,024.19 68.08 234.02 2,884.22 1,400.65 -1,400.65 -1,707.44 1.10 4,116.12 67.82 233.43 2,918.74 1,451.06 -1,451.06 -1,776.13 0.66 4,209.22 66.78 233.27 2,954.66 1,502.33 -1,502.33 -1,845.04 1.13 4,301.85 66.16 233.23 2,991.64 1,553.14 -1,553.14 -1,913.09 0.67 4,392.57 65.78 232.98 3,028.59 1,602.89 -1,602.89 -1,979.35 0.49 4,485.66 65.97 233.60 3,066.64 1,653.67 -1,653.67 -2,047.46 0.64 4,579.61 65.84 232.96 3,104.99 1,704.95 -1,704.95 -2,116.20 0.64 4,672.32 65.63 231.92 3,143.09 1,756.47 -1,756.47 -2,183.20 1.05 4,765.03 64.96 230.67 3,181.84 1,809.13 -1,809.13 -2,248.93 1.42 4,855.65 65.16 230.17 3,220.05 1,861.49 -1,861.49 -2,312.26 0.55 4,869.57 65.11 230.15 3,225.91 1,869.58 -1,869.58 -2,321.96 0.38 4,959.62 65.83 230.60 3,263.29 1,921.82 -1,921.82 -2,385.06 0.92 5,052.34 67.44 230.66 3,300.06 1,975.81 -1,975.81 -2,450.86 1.74 5,146.51 67.94 231.04 3,335.81 2,030.82 -2,030.82 -2,518.42 0.65 5,238.93 67.62 231.91 3,370.76 2,084.11 -2,084.11 -2,585.35 0.94 5,330.93 66.42 229.85 3,406.68 2,137.54 -2,137.54 -2,651.06 2.44 5,421.69 64.94 227.42 3,444.06 2,192.18 -2,192.18 -2,713.13 2.93 5,514.43 64.90 227.06 3,483.37 2,249.21 -2,249.21 -2,774.80 0.35 5,608.06 64.79 227.96 3,523.17 2,306.45 -2,306.45 -2,837.30 0.88 5,699.60 64.79 229.93 3,562.17 2,360.84 -2,360.84 -2,899.74 1.95 5,793.29 64.76 232.01 3,602.10 2,414.21 -2,414.21 -2,965.58 2.01 5,884.77 64.80 233.84 3,641.08 2,464.10 -2,464.10 -3,031.61 1.81 5,977.75 64.57 234.42 3,680.84 2,513.35 -2,513.35 -3,099.72 0.62 6,071.02 64.78 234.34 3,720.73 2,562.45 -2,562.45 -3,168.25 0.24 6,163.31 64.64 234.53 3,760.16 2,610.99 -2,610.99 -3,236.13 0.24 6,255.40 64.64 234.58 3,799.60 2,659.24 -2,659.24 -3,303.92 0.05 6,348.83 64.62 235.10 3,839.64 2,707.86 -2,707.86 -3,372.94 0.50 6,441.54 64.62 235.56 3,879.37 2,755.51 -2,755.51 -3,441.83 0.45 6,534.39 64.62 235.71 3,919.17 2,802.86 -2,802.86 -3,511.07 0.15 6,627.16 64.68 235.79 3,958.89 2,850.04 -2,850.04 -3,580.37 0.10 6,720.81 64.64 235.11 3,998.97 2,898.04 -2,898.04 -3,650.08 0.66 6,811.76 64.65 234.17 4,037.92 2,945.61 -2,945.61 -3,717.11 0.93 6,904.52 64.64 233.55 4,077.64 2,995.04 -2,995.04 -3,784.80 0.60 6,997.88 64.62 232.06 4,117.64 3,046.04 -3,046.04 -3,852.00 1.44 2E-02 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 7,090.24 64.26 230.46 4,157.50 3,098.17 -3,098.17 -3,916.99 1.61 7,183.95 64.13 229.60 4,198.29 3,152.37 -3,152.37 -3,981.64 0.84 7,274.33 64.37 228.72 4,237.55 3,205.60 -3,205.60 -4,043.23 0.92 7,367.45 64.55 228.62 4,277.70 3,261.09 -3,261.09 -4,106.32 0.22 7,462.22 64.66 229.02 4,318.35 3,317.46 -3,317.46 -4,170.75 0.40 7,554.35 64.96 229.48 4,357.56 3,371.88 -3,371.88 -4,233.91 0.56 7,647.05 65.19 229.89 4,396.62 3,426.27 -3,426.27 -4,298.01 0.47 7,737.49 65.12 231.03 4,434.63 3,478.51 -3,478.51 -4,361.30 1.15 7,828.15 65.18 232.01 4,472.73 3,529.70 -3,529.70 -4,425.70 0.98 7,922.94 65.08 232.71 4,512.59 3,582.22 -3,582.22 -4,493.80 0.68 8,015.71 65.01 232.96 4,551.73 3,633.03 -3,633.03 -4,560.83 0.26 8,108.53 65.15 233.64 4,590.84 3,683.34 -3,683.34 -4,628.32 0.68 8,201.55 65.09 233.68 4,629.98 3,733.34 -3,733.34 -4,696.29 0.08 8,295.16 65.05 233.36 4,669.43 3,783.81 -3,783.81 -4,764.55 0.31 8,386.86 65.06 233.51 4,708.11 3,833.34 -3,833.34 -4,831.33 0.15 8,480.44 65.12 233.74 4,747.52 3,883.68 -3,883.68 -4,899.66 0.23 8,572.33 65.22 233.50 4,786.11 3,933.15 -3,933.15 -4,966.81 0.26 8,666.54 65.16 233.50 4,825.64 3,984.01 -3,984.01 -5,035.55 0.06 8,755.96 65.15 232.81 4,863.21 4,032.67 -4,032.67 -5,100.48 0.70 8,850.09 65.16 231.94 4,902.77 4,084.82 -4,084.82 -5,168.14 0.84 8,942.14 65.15 231.08 4,941.44 4,136.80 -4,136.80 -5,233.52 0.85 9,035.15 65.05 230.95 4,980.60 4,189.88 -4,189.88 -5,299.09 0.17 9,127.23 65.09 230.49 5,019.42 4,242.74 -4,242.74 -5,363.73 0.46 9,221.17 65.11 229.97 5,058.97 4,297.25 -4,297.25 -5,429.22 0.50 9,312.93 65.51 229.15 5,097.30 4,351.33 -4,351.33 -5,492.67 0.92 9,405.58 65.69 229.53 5,135.57 4,406.31 -4,406.31 -5,556.68 0.42 9,497.49 65.81 230.36 5,173.32 4,460.23 -4,460.23 -5,620.82 0.83 9,590.87 65.72 231.45 5,211.65 4,513.93 -4,513.93 -5,686.90 1.07 9,683.59 65.68 231.89 5,249.81 4,566.34 -4,566.34 -5,753.19 0.43 9,775.20 65.90 232.40 5,287.38 4,617.61 -4,617.61 -5,819.16 0.56 9,867.85 66.06 232.85 5,325.09 4,668.98 -4,668.98 -5,886.41 0.48 9,961.14 66.16 231.58 5,362.87 4,721.24 -4,721.24 -5,953.82 1.25 10,051.54 66.19 230.79 5,399.39 4,773.07 -4,773.07 -6,018.26 0.80 10,145.71 66.28 231.55 5,437.34 4,827.11 -4,827.11 -6,085.40 0.74 10,236.74 66.19 232.36 5,474.02 4,878.46 -4,878.46 -6,151.00 0.82 10,330.63 66.23 231.82 5,511.90 4,931.24 -4,931.24 -6,218.79 0.53 10,423.27 65.62 231.21 5,549.69 4,983.88 -4,983.88 -6,285.00 0.89 10,514.58 65.14 230.74 5,587.73 5,036.14 -5,036.14 -6,349.48 0.70 10,609.10 65.41 229.58 5,627.26 5,091.15 -5,091.15 -6,415.40 1.15 10,699.26 65.28 228.87 5,664.87 5,144.66 -5,144.66 -6,477.45 0.73 10,794.28 65.34 228.06 5,704.57 5,201.90 -5,201.90 -6,542.08 0.78 2E-02 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) N/-S E/-W Dogleg Rate (o/100ft) 10,886.37 65.44 225.53 5,742.92 5,259.22 -5,259.22 -6,603.10 2.50 10,977.51 65.33 222.76 5,780.89 5,318.67 -5,318.67 -6,660.80 2.77 11,071.39 65.73 220.11 5,819.78 5,382.72 -5,382.72 -6,717.34 2.60 11,162.31 66.81 216.72 5,856.38 5,447.93 -5,447.93 -6,769.04 3.61 11,255.99 69.05 213.09 5,891.58 5,519.12 -5,519.12 -6,818.68 4.31 11,348.83 71.53 210.29 5,922.90 5,593.48 -5,593.48 -6,864.57 3.90 11,440.90 74.26 209.73 5,949.98 5,669.68 -5,669.68 -6,908.58 3.02 11,533.26 76.88 209.20 5,972.99 5,747.55 -5,747.55 -6,952.57 2.89 11,625.27 78.20 208.64 5,992.84 5,826.19 -5,826.19 -6,996.01 1.55 11,719.97 78.55 206.16 6,011.93 5,908.53 -5,908.53 -7,038.70 2.59 11,811.21 78.26 204.63 6,030.27 5,989.27 -5,989.27 -7,077.03 1.67 11,905.50 77.24 203.30 6,050.27 6,073.47 -6,073.47 -7,114.45 1.75 11,997.63 76.96 200.88 6,070.84 6,156.67 -6,156.67 -7,148.22 2.58 12,090.29 76.40 199.58 6,092.19 6,241.27 -6,241.27 -7,179.40 1.49 12,184.40 78.38 197.58 6,112.74 6,328.32 -6,328.32 -7,208.66 2.95 12,275.51 81.43 195.44 6,128.71 6,414.31 -6,414.31 -7,234.14 4.07 12,368.61 83.97 192.11 6,140.54 6,503.98 -6,503.98 -7,256.11 4.48 12,461.58 84.42 189.67 6,149.95 6,594.80 -6,594.80 -7,273.58 2.66 12,505.86 83.36 189.18 6,154.66 6,638.23 -6,638.23 -7,280.79 2.63 12,570.00* 83.36 189.18 6,162.08 6,701.13 -6,701.13 -7,290.96 0.00 *Projection to bit. 2E - 0 2 29 5. 2 B i t R e c o r d Bi t # Si z e M a k e Ty p e / Se r i a l # Je t s / TF A De p t h I n MD / T V D To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) Av g . WO B (K l b s ) Av g RP M Av g PP (p s i ) Wear BHA # 1 9 7 / 8 ” H a l l i b u r t o n PD C / 11 7 1 0 8 7 9 5x 1 3 , 1x 1 4 4, 9 5 0 ’ / 3, 2 5 9 ’ 7, 6 2 0 ’ 88 . 2 5 14 5 . 2 1 0 . 2 15 0 . 3 27 1 0 1 - 1 - W T - A - X - N - T D 1 2E - 0 2 30 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O Mu d T y p e : D r i l l P l e x Da t e D e p t h / T V D M W V I S P V Y P G e l s F L F C S o l O / W S d A l k C l C a ECD @ bit 8/ 3 0 / 2 0 1 4 4 , 9 5 0 ’ / 2 , 5 3 7 ’ 9 . 8 — 1 3 1 8 2 3 / 2 9 / 3 8 N C N C 9 1 / 9 0 T R 1 . 1 6 0 0 2 0 — 8/ 3 1 / 2 0 1 4 4 , 9 5 0 ’ / 2 , 5 3 7 ’ 9 . 7 — 1 5 1 5 6 / 1 4 / 2 3 N C N C 9 1 / 9 0 T R 2 . 4 6 0 0 2 0 — 9/ 1 / 2 0 1 4 4 , 9 7 0 ’ / 2 , 5 3 7 ’ 9 . 8 — 1 3 1 5 8 / 1 4 / 2 2 N C N C 9 1 / 9 0 T R 2 . 5 6 0 0 2 0 — 9/ 2 / 2 0 1 4 7 , 0 6 1 ’ / 4 , 1 1 5 ’ 9 . 8 5 8 1 4 3 4 1 3 / 1 6 / 1 6 3 . 8 1 / - 8 2 / 9 0 1 . 7 5 0 0 2 0 1 1 . 8 2 9/ 3 / 2 0 1 4 9 , 5 1 0 ’ / 5 , 1 8 0 ’ 9 . 8 5 6 1 5 2 7 1 1 / 1 3 / 1 4 3 . 7 1 / - 9 2 / 8 9 . 2 5 . 3 8 4 5 0 2 0 1 1 . 2 1 9/ 4 / 2 0 1 4 1 1 , 6 9 4 ’ / 6 , 0 0 5 ’ 1 0 . 2 4 8 1 6 2 1 9 / 1 8 / 2 5 2 . 7 1 / - 9 3 / 8 8 . 2 5 . 4 6 0 0 2 0 1 1 . 3 4 9/ 5 / 2 0 1 4 1 2 , 5 7 0 ’ / 6 , 1 6 1 ’ 1 0 . 2 4 8 1 3 2 8 1 1 / 1 5 / 1 7 3 1 / - 1 0 . 5 4 / 8 6 . 2 5 . 5 5 5 0 2 0 1 1 . 1 5 9/ 6 / 2 0 1 4 1 2 , 5 7 0 ’ / 6 , 1 6 1 ’ 1 0 . 2 5 0 1 2 2 2 8 / 1 0 / 1 1 3 1 / - 1 0 . 5 4 / 8 6 . 2 5 0 . 5 5 5 0 2 0 — 9/ 7 / 2 0 1 4 1 2 , 5 7 0 ’ / 6 , 1 6 1 ’ 1 0 . 3 5 0 1 1 2 0 8 / 1 0 / 1 1 3 1 / - 1 0 . 5 4 / 8 6 . 2 5 0 . 5 5 0 0 2 0 — Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h O / W = O i l t o W a t e r r a t i o C a = C a l c i u m ( H a r d n e s s ) VI S = F u n n e l V i s c o s i t y F L = F i l t r a t e ( F l u i d ) L o s s S d = S a n d C o n t e n t ( % ) E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y PV = P l a s t i c V i s c o s i t y F C = F i l t e r C a k e A l k = A l k a l i n i t y YP = Y i e l d P o i n t S o l = S o l i d s ( % ) C l = C h l o r i d e s 31 6 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:12,050 MD 12,570 MD Country:6,082.78 TVD 6,162.08 TVD Averages Before During After Maximum ROP (fph)120.9 73.4 N/A 203.9 WOB 11.7 9.6 N/A 17 RPM 162 161 N/A 171 Mud Weight 10.2 10.2 N/A 10.2 Chloride 550 550 N/A 550 Total Gas 61.3 114.2 N/A 410.0 C1 (ppm)8,426 10,571 N/A 68,228 C2 (ppm)646 1,041 N/A 8,112 C3 (ppm)324 509 N/A 3,902 C4 (ppm)148 368 N/A 3,025 C5 (ppm)211 253 N/A 1,766 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 50%Type Instant Amount Amount none Distribution Even Intensity Moderate Color Color n/a Intensity Strong Color Bright Residual Fluorescence Cut Color Bright Yellow White Intesity Color N/A Color Oil Show Rating Free Oil in Mud Comments Report by:Allen Odegaard / James Adams Please Note: there are no "after" numbers on the above chart because CANRIG was released before the drilling of the production section. Good White Blue Bright Yellow Strong Conoco-Philips Alaska Inc 50-029-23516-00-002E-01 Kuparuk River Unit Doyon 141 9/5/2014 2:42 40% North Slope Alaska USA Carbonaceous Siltstone = brown, medium dark gray-- very dark gray; brittle; platy to flaky cuttings habit; dull luster; granular; unconsolidated; thin structure with laminae; reaction with HCl; abundant quartz and black sand; calcite fragments; trace pyrite; yellow, bright, mineral fluorescence with a fast, transparent to white cut. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 33 7 DAILY REPORTS 34 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/01/2014 Time: 0600 Current Depth (MD): 4949’ Current Depth (TVD): 2537’ Current Operations: POOH 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: Torque: Current:0 Max: WOB: Current 74.9 Max: RPM: Current:0 Max: PP: Current: 2206 Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 4949’ MW: 9.7 FV: - PV:15 YP:15 FL: NC Gels: 6/14/23 Sol: 9 pH:10.7 Cl-:600 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection Gases NA C1 C2 C3 C4I C4N C5I C5N None 35 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Pump cement, drop top plug, 128 bbls cement @ surface. Test BOP – no test. Fix BOP and retest. POOH @ 0250. Failures: 36 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/02/2014 Time: Current Depth (MD): Current Depth (TVD): Current Operations: Drilling ahead 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 5483’ MW: 9.8 FV: - PV:13 YP:15 FL: NC Gels: 8/14/22 Sol: 9 pH:11.0 Cl-:600 Ca++: 20 MW Change: Depth: 4970 From:9.7 To:9.8 Reason: UNK Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None 37 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Carbonaceous siltstone w. trace sand Last 24 hrs: Operational Summary: .Perform FIT, RIH, Drill ahea Failures: 38 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/03/2014 Time: 0400 Current Depth (MD): 7675 Current Depth (TVD): 4412 Current Operations: DRILLING AHEAD 24 hr Footage (MD): 2705 Drilling Parameters ROP: Current: 117 Max: 690 Torque: Current:10.7 Max: 23004 WOB: Current 42.6 Max: 88.70 RPM: Current:160 Max: 162 PP: Current: 69 Max: 2732 Lag: Strokes: 3365 Time: 28.76 Surf-Surf: Strokes:6779 Time: 35.36 ECD: Current: 11.82 Max: 11.82 Mud Properties @ 4151’ MW: 9.8 FV: 58 PV 14 YP:34 FL: @ Gels: 13/16/16 Sol: 8 pH:10.0 Cl-:500 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 38 Max: 334 Depth (MD/TVD): 9544 Avg BG : 18 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None X 39 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6961’ 11 2059 349 7044’ 20 3899 735 7155’ 18 3653 681 7224’ 12 2435 420 7327’ 14 2831 514 7467’ 17 5436 33 7524’ 15 5158 41 7584’ 11 4542 34 Lithologies: Current: Last 24 hrs: Claystone, siltstone, unconsolidated sand. Operational Summary: .Drilling ahead from 4970’. Failures: 40 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/04/2014 Time: 0400 Current Depth (MD): 7675 Current Depth (TVD): 4412 Current Operations: DRILLING AHEAD 24 hr Footage (MD): 2705 Drilling Parameters ROP: Current: 117 Max: 690 Torque: Current:10.7 Max: 23004 WOB: Current 42.6 Max: 88.70 RPM: Current:160 Max: 162 PP: Current: 69 Max: 2732 Lag: Strokes: 3365 Time: 28.76 Surf-Surf: Strokes:6779 Time: 35.36 ECD: Current: 11.82 Max: 11.82 Mud Properties @ 4151’ MW: 9.8 FV: 58 PV 14 YP:34 FL: @ Gels: 13/16/16 Sol: 8 pH:10.0 Cl-:500 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 38 Max: 334 Depth (MD/TVD): 9544 Avg BG : 18 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None X 41 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6961’ 11 2059 349 7044’ 20 3899 735 7155’ 18 3653 681 7224’ 12 2435 420 7327’ 14 2831 514 7467’ 17 5436 33 7524’ 15 5158 41 7584’ 11 4542 34 Lithologies: Current: Last 24 hrs: Claystone, siltstone, unconsolidated sand. Operational Summary: .Drilling ahead from 4970’. Failures: 42 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/05/2014 Time: 0400 Current Depth (MD):12147’ Current Depth (TVD): 6105.67’ Current Operations: DRILLING AHEAD 24 hr Footage (MD): 4472’ Drilling Parameters ROP: Current: 104.88 Max: 1767.68 Torque: Current:16.4 Max: 20112 WOB: Current 10.1 Max: 167.4 RPM: Current:160 Max: 171 PP: Current: 2999 Max: 3553 Lag: Strokes: 8148 Time: 49.99 Surf-Surf: Strokes:10125 Time: 62.12 ECD: Current: 11.34 Max: 11.5 Mud Properties @ 4151’ MW: 10.2 FV: 48 PV 16 YP:21 FL: 2.7 Gels: 9/18/25 Sol: 9 pH:9.8 Cl-:600 Ca++: 20 MW Change: Depth: - From:10.1 To:10.2 Reason: Delivered at 10.1; weighting up Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 334 Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR 4911’/3242.54’ - 11304’/5912.73’ 218.53 45.78 134.50 Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas - Connection Gases - C1 C2 C3 C4I C4N C5I C5N None 43 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Claystone, carbonaceous siltstone, unconsolidated sand. Operational Summary: . Failures: Data import into DML. 44 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/06/2014 Time: 0400 Current Depth (MD):12570’ Current Depth (TVD): 6162.08’ Current Operations: PUMPING OUT OF THE HOLE. 24 hr Footage (MD): 423’ Drilling Parameters ROP: Current: 0 Max: 203.88 Torque: Current:7 Max: 17723 WOB: Current 0 Max: 14.9 RPM: Current:0 Max: 163 PP: Current: 362 Max: 3443 Lag: Strokes: 8797 Time: 53.97 Surf-Surf: Strokes:10939 Time: 67.11 ECD: Current: 11.15 Max: 11.28 Mud Properties @ MW: 10.2 FV: 48 PV:13 YP:28 FL: 3 Gels: 11/15/17 Sol: 10.5 pH:9.7 Cl-:550 Ca++: 20 MW Change: none Depth: From: To: Reason: Mud Loss event: Depth: n/a Volume:n/a Gas Data Ditch Gas: Current: 0 Max: 410.69 Depth (MD/TVD): 12564’/6160.14’ Avg BG : 122U LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR 4911’ – 12532’ / 3243.39’ – 6157.88’ 470.89 45.77 140.12 Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas n/a Connection Gases 12121’/6099.46’ 408U C1 C2 C3 C4I C4N C5I C5N None 45 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Sand. Last 24 hrs: Carbonaceous claystone, siltstone, sand. Operational Summary: Drilling ahead from 112147’. TD well @ 12570’. Pump OOH to 9752’. Failures: 46 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/07/2014 Time: 0400 Current Depth (MD):12570’ Current Depth (TVD): 6162.08’ Current Operations: POOH on elevators, monitor well, POOH. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: - Max: - Torque: Current:- Max: - WOB: Current - Max: - RPM: Current:- Max: - PP: Current: - Max: - Lag: Strokes: 8797 Time: 53.97 Surf-Surf: Strokes:10939 Time: 67.11 ECD: Current: - Max: - Mud Properties @ MW: 10.2 FV: 50 PV:12 YP:22 FL: @ Gels: 8/10/11 Sol: 10.5 pH:10.0 Cl-:550 Ca++: 20 MW Change: none Depth: From: To: Reason: Mud Loss event: Depth: n/a Volume:n/a Gas Data Ditch Gas: Current: 0 Max: 269.37 Depth (MD/TVD): 1270’/6128.08’ Avg BG : 6U LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR 4911’ – 12570’ / 3243.39’ – 6161’ 470.89 45.78 140.13 Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas n/a Connection Gases n/a C1 C2 C3 C4I C4N C5I C5N None 47 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Sand. Last 24 hrs: Carbonaceous claystone, siltstone, sand. Operational Summary: POOH F/9843’ T/4935’ MD. Cont POOH on elevators to 760’ MD. Monitor well. Failures: 48 ConocoPhillips Alaska, Inc. 2E-01 Daily Geologic Report Report for: Phillip Bottrell Date: 9/08/2014 Time: 0400 Current Depth (MD): 12570’ Current Depth (TVD): 6161’ Current Operations: RIH W. Casing T 12588’ MD 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: - Max: - Torque: Current:- Max: - WOB: Current - Max: - RPM: Current:- Max: - PP: Current: - Max: - Lag: Strokes: 8797 Time: 53.97 Surf-Surf: Strokes:10939 Time: 67.11 ECD: Current: - Max: - Mud Properties @ MW: 10.3 FV: 50 PV:11 YP:20 FL: @ Gels: 8/10/11 Sol: 10.5 pH:9.6 Cl-:500 Ca++: 20 MW Change: none Depth: From: To: Reason: Mud Loss event: Depth: n/a Volume:n/a Gas Data Ditch Gas: Current: 0 Max: 24.01 Depth (MD/TVD): 12570’/6161’ Avg BG : 6U LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR Res1 Res2 Res23 Neutron Sonic Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas n/a Connection Gases n/a C1 C2 C3 C4I C4N C5I C5N None 49 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Sand. Last 24 hrs: Carbonaceous claystone, siltstone, sand. Operational Summary: Rig up casing tools, RIH with 75/8” casing T 8718’ MD. Failures:
