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214-139
21 41 39 VS -11. PRGAcnvE DIAGNOSTIC SERVICES, INC. WELL LOG MANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams 130 West International Airport Road Suite C MAY Z 1 2019 Anchorage, AK 99518 n o��� DdsanchoraaeO-memorvloa com A 01 -May -19 1D-146 CD 50-029-23527-00 Date :0Wq PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEO.MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM 30 82 4 D:`Aehives\MastefrsiplatsRles'TompL kslDutnbvtio�\TeanemittalSheeGt^onomPlWlips_Tce .A.docc w Company: Log Date: Log No.: Run No.: Pipe Description: Pipe Use: Pipe Description: Pipe Use: ConocoPhillips Alaska, Inc. May 1, 2019 15681 1 4.5 inch 12.6 Ib. L-80 EUE 8RD Tubing 3.5 inch 9.3 Ib. L-80 EUE 8RD 214139 3p824 Memory Multi -Finger Caliper Log Results Summary Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: 1 D-146 West Sak Alaska 50-029-23527-00 Surface 68 Ft. (MD) 68 Ft. (MD) 7,136 Ft. (MD) This caliper data is tied into the top of the D Nipple at 7,135.5 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5 inch and 3.5 inch tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The body region analysis and joint tabulation data for the 4.5 inch and 3.5 inch tubing are combined. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 13%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. B. Suhanek C. Waldrop E. Zimba � ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565 9085 Fax: (231) 431-7125 E-mail: PDSAnalvsis(o)memorvloa com Prudhoe Bay Field Office Phone: (907) 659-2307 Far: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (12.9'-68.1') Well: ID -146 Pipe 2 3.5 in (68.1' - 7,1 36.4') Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 1, 2019 ■ Approx. Tool Deviation . Approx. Borehole Profile 28 25 799 50 1,588 75 2,379 GLM 1 J 100 Z 125 3,199 E c LL 0 C 3,984 a 150 175 w 4,772 GLM 2 5,587 GLM 3 6,375 221.2 7,136 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 221.2 J Z 125 c 0 150 175 Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 EYE BIRD 3.958 in. 13 ft. 68 ft. Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 0 0 0 0 0 Damage Profile (%wall) 1111M Penetration body =1111 Metal loss body 0 50 100 GLM 1 (8:00) GLM 2 (1:00) GLM 3 (10:30) Bottom of Survey = 221.2 PDS Report Overview Body Region Analysis Well: iD-146 Survey Date: May 1, 2019 Field: West Sak Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Anal ,t - Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 EYE BIRD 3.958 in. 13 ft. 68 ft. Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 0 0 0 0 0 Damage Profile (%wall) 1111M Penetration body =1111 Metal loss body 0 50 100 GLM 1 (8:00) GLM 2 (1:00) GLM 3 (10:30) Bottom of Survey = 221.2 cps. Well: 1 D-146 Field: West Sak Company: ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Survey Date: May 1, 2019 Analyst: Waldrop Sheet Pipe Descripfion 4.5 in. 12.6 ppf L-80 EUE 8RD Tubing 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 13 ft 68 ft 2.992 in. 0.254 in. 68 ft 7,136 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 .1 13 0 0.01 5 1 89 Pur)e its. 2.1 68 0 0 0 0 2.94 4.5" X 35" CROSS-OVER 2.2 70 0 0.02 8 2 2.93 Pup Lt. Deposits. 2.3 80 0 E03 11 4 2.93 Pun Lt. De its. 82 1 00.02 6 2 .94 4 114 1 0 0.02 7 2 2.94 5 1461 6 2.95 177 0 0.0. 02 8 4 5 7 209 0 0.02 8 3 2.93 24 0 0.02 7 .94 ?79 0 0.01 5 2 2.94 10 304 00.02 6 3 2.94 1 3 0 0.01 6 2 .94 2 367 0 0 2 4 13 399 0 0.02 6 2 2.95 14 430 0 026 2 2. 5 14.1 461 0 0.03 13 4 2. Pwu I.L.Deposits. 14.2 471 0 0 0 0 2.87 3.5" CAMCO DS NIPPLE 14.3 473 0 0 11 2 2.92 Pu , De sits. 15 483 0 0.01 5 1 2.94 16 515 3 2.94 17 546 0. 9 2.94 18 578 0 0.02 7 2 2.94 1 610 6 2 2. 20 641 0 I 0.01 5 1 .95 21 673 0 0.02 7 3 2.94 22 1 704 n nj 5 1 2. 3 1 736 1 0 1 0.02 6 2 .9 24 767 1 0.02 7 3 2.95 5 799 06 2.95 6 31 0 0.02 9 94 27 1 862 1 0 0.02 7 2 2.94 28 1 894 0 0.01 6 4 2.94 9 925 0 0.02 7 2 .94 30957 0 0.01 6 1 2.94 31 980 0.02 6 .93 Lt. osits. 32 1020 0 0.02 7 2 2.94 33 1 1051 1 0 0. 9 2 2. 34 1 10,93 1 0 0. 6 .94 351114 1 0 0.01 5 1 2.94 1146 1 0 1 0.01 5 2 2. 4 37 1177 1 0 1 0.01 6 1 2.92 sits. 38 1209 0 0.02 7 1 2.92 Lt. De osits. 9 1240 0 0.02 6 1 2. 40 1272 1 0 7 2 2.9 Lt. osits. 41'30 0 0.02 6 2 2.95 4 33 0 .0 2 2. 5 4 13677 1 2. 44 1 1398 0 0.02 7 1 2.92 Lt. De osits. Penetration Body Metal Loss Body Page 1 ji S- Well: 1 D-146 Field: West Sak Company: ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Survey Date: May 1, 2019 Analyst: Waldrop Sheet Pipe Description 4.5 in. 12.6 ppf L-80 EUE 8RD Tubing 3.5 in. 9.3 ppf L-80 EUE BRD Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 13 ft 68 ft 2.992 in. 0.254 in. 68 ft 7,136 ft. Joint Jr. Depth No. (Ft.) Pen. Upset (i n.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (i n.) Comments Damage Profile (% wall) 0 50 100 45 1430 1 0 1 0.01 6 1 2. 46 1462 0 0.02 8 2 2.94 47 4 0 0.01 2 2.94 48 1525 0 0.01 6 1 2.95 49 0 0.02 9 2 2.95 1588 5 2 2. 5 51 1620 0 0.01 5 1 2.95 1651 0 1 1 2. 4 53 1683 0 6 1 .94 54 1715 0 0.01 5 1 2.94 55 1746 0 1 5 1 2.9 56 8 0. 1 5 1 .94 57 1810 0 0.01 6 1 2.93 5 1841 0 0.0 6 2 .95 59 1873 0 0. 2 6 1 2.94 60 1905 0 0.02 6 2 2.94 61 --1936 0 0.02 7 1 2,94 62 1968 0 1 002 6 2 2.94 63 1999 0 5 1 2.94 64 2031 0 1 65 2063 0 9 4 2.94 66 94 6 4 67 21 6 0 JO.O 2 2. 4 68 2157 0 6 1 2.94 69 0 5 2 4 70 22 0 3 2. 4 71 2252 0 5 1 2.95 72 2284 0 0.02 7 1 2.94 73 2316 0 om 6 2 2.9 74 2347 0 0.02 6 1 2.94 75 237 0 0.02 2 2.94 7 2411 01 5 1 .93 77 2442 0 0.02 8 2 2.94 7824 0 0.02 7 2 2 4 9 250 0 7 1 .94 80 2537 1 0 0.02 6 1 2.94 8 20 1 OD2 2 2. 82 2600 0 0.02 7 1 2.94 83 2632 0 0.02 4 2. 5 83.1 2664 0 0.03 1 3 2. 1 u t De o f 83.2 2674 0 0 0 0 2.88 CIM 1 11 ATCH @ 8:00 83.3 83 0 0.03 0 2 2.93 Pu 84 2693 0 1 0.02 7 2 2. 0.01 6 1 2.93 0.0 7 9 0.02 3 2.94 M282 0.02 7 1 2.95 0.02 95 0.02 7 2 5 0.02 8 4 2.96 Penetration Body Metal Loss Body Page 2 JiS- Well: 1 D-146 Field: West Sak Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: May 1, 2019 Analyst: Waldrop Pipe Descrip don 4.5 in. 12.6 ppf L80 EUE BIRD 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing Tubing Nom. ID 3.958 in. 2.992 in. Body Wall Top Depth Bottom Depth 0.271 in. 13 ft 68 ft 0.254 in. 68 ft 7,136 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (i n.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (i n.) --j.-94 Damage Profile Comments (%wall) 0 50 100 92 2 7 0 2 93 297802 -7-1 2.95 94 3010 0 :02 7 2 2.95 95 3041 0 0.02 6 2 2.95 96 3073 0 7 1 2.96 97 3 4 0. 2 6 1 2.95 98 3136 0 0.02 7 2 2.95 99 16 0 7 3 2. 100 3199 0 0.02 2. Lt. Den -;-- its101 101 3231 0 0.02 8 2 2.95 102 3261 00. 7 2. 103 3293 0 002 7 2 .95 104 3325 0 0.02 8 2 2.94 05 0 0.02 7 .94 1 3387 0 .02 2 4 107 3419 0 0.02 7 2 2.94 1 345 0 0.02 7 1 2.95 109 3482 0 02 2 . 5 110 3514 0 0.02 7 1 2.95 711 3545 0 0.03 1 4 2.95 112 3577 0 0.03 13 2 2.95 113 3609 0 0.02 8 .94 114 3640 0.02 1 . 5 115 3672 0 0.02 S 2 2.95 11 370 0 2 7 2 2.95 117 735 0 0.01 6 2. 4 718 3766 0 0.01 5 1 2.95 11 3795 0 Q Q9 6 1 2 5 120 1 3830 1 0 RO-2 9 1 2. 4 121 3861 1 0 1 0.02 6 2 2.94 122 3893 1 0 0.02 7 2 2 9 Lt. ocife 123 1 3923 1 0 0. 8 22. 124 3955 0 0.02 8 2 2.94 1 984 0 0. 8 2 2. 4 126 1 4015 1 0 0.0 8 3 2.9 1 Lt. osit . 127 4046 0 0.02 8 2 2.94 1 077 0. 10 2 2. 129 4109 0 0.02 7 1 2.94 30 414 0 7 2 4 131 172 0 0 732 4204 0 0.02 9 2 2.95 133 423 0 .02 2 4 134 4267 0 0028 3 9 135 4298 0 0.02 8 5 2.94 36 432 0 002 2 .94 137 4361 1 0 03 III17 2 5 138 4392 00.03 10 2 2.94 139 4424 0 0.02 7 5 140 1 4455 0 1 2.95 141 1 4487 0 1 0.02 1 7 1 4 1 2.95 Penetration Body Metal Loss Body Page 3 CPS � Well: ID -146 Field: West Sak Company: ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 1, 2019 Analyst: Waldrop Sheet Pipe Description 4.5 in. 12.6 ppf LSO EUE 8RD Tubing 3.5 in. 9.3 ppf L-80 DUE 8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 13 ft 68 ft 2.992 in. 0.254 in. 68 ft 7,136 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 142 4519 .0 9 4 2.95 1434550 0 0.01 6 2 2.95 144 58 0 002 7 3 2.95 145 4614 0 0.02 7 3 2.95 146 4645 0 Q,Q2 7 2 2.95 47 4677 0 0.02 7 2 2.96 1484708 0 0.02 8 3 2.95 149 4740 6 2 150 4772 0 0.02 7 4 2.94 151 4803 0 0.02 7 2 2.94 152 4 35 0 0.02 7 1 .95 153 4866 1 0 1 0.02 7 4 .94 154 4898 0 0.02 7 2 2.95 A"'0 0.02 6 .94 7 4961 0 .02 2 4 157 4992 0 0.02 9 2 2.94 8 52 3 0 1 0.2 7 1 4 159 5054 1 0 6 2 2 5 160 5086 0 0.02 7 3 2.94 161 5117 0 0.02 6 1 94 162 5148 0 0.02 6 2 2.95 .1 5179 0 0.02 8 2 3 Lt osit 162.2 5190 0 0 0 2. G M2 LATCH 0 1: 0 162.3 "990 0.03 11 3 2.92 Pu Lt. De osits. 163 52 0 .0 5 2 4 164 1 5240 1 0 1 0. 7 2 2. 165 5272 0 0.02 9 2 2.94 1 30 .0 7 1 167 335 0. 7 2 168 5366 0 0.01 6 2 2.95 16 5398 0 1 170 4 9 0. 7 1 2. 171 5461 0 0.02 7 2 2.9 17 5492 0 6 2 4 17 524 0. 2 8 3 2.9 174 5556 0 0.02 7 4 2.95 17 87 0 1 0.02 7 2 2.9 176 5619 1 0 1 0.02 7 2 2.92 Lt. De osits. 177 5648 1 0 02 7 2 4 5679 1 5 1 2. 117 179 5710 0 0.02 7 2 2.95 80 5742 0 1 0.027 2 294 181 5773 0 1 0.029 4 2. 182 5805 0 0.02 9 4 2.95 83 5837 0 0.02 7 2 2.9 184 5868 0 n.02 7 2 2. 4 185 5900 0 0.02 9 4 2.94 186 5931 0 0.02 6 2 .95 187 5963 0 7 2 2. 4 188 5995 0 0.02 1 6 1 1 2.93 Penetration Body Metal Loss Body Page 4 cps-, Well: Field: Company: 1 D-146. West Sak ConocoPhillips Alaska, Inc PDS Report Joint Tabulation Survey Date: May 1, 2019 Analyst: Waldrop Sheet Pipe Description 4.5 in. 12.6 ppf L-80 EUE 8RD Tubing 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 13 ft 68 ft 2.992 in. 0.254 in. 68 ft 7,136 ft. Joint 1t. Depth Pen, No. (Ft.) Upset (in.) Pen. Body (i n.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 189 6026 0 0.02 7 2 4 190 6058 0 0.02 6 2 2.95 191 6090 0 0. 8 .94 192 6121 0 0.02 7 2 2.95 19 6153 0 G .94 194 61 0.0 4 195 6216 0 0.0294 196 6 8 0 0. 94 19 0.024 198 6311 0 0.02 94 199 343 0.05 W2.94 0 7 0 0 4 201 6406 0 0.02 401.1 4 0 .03 9 Pu t. e1. 6448 0 9 GLM 3 ATCH 10:3 201.3 6457 0 0.03 12 4 2.92 Pu Lt. De osits. 202 6468 1 0 .0 7 2 2.94 203 1 6499 1 0 O.OT 7 1 .94 2046531 0 0.02 7 2 2.95 6563 0 0.02 7 2 4 206 65950 0.02 8 3 2.94 07 66,6 2 7 3 2. 6658 1 0 1 Q 02 7 2 .95 209 6690 0 0.02 7 2 2.94 6722 0 0. 7 2 .95 211 1 6753 0 1 0.03 10 5 2126785 0 0.02 6 2 2.94 1 6816 8 .94 214 6848 0 0.02 7 1 94 2156880 0 0.02 6 2 2.94 6912 0. 7 1 .94 217 6943 0 0.02 6 1 95 21116975 0 0.02 7 2 2.94 219 70070 0.0 6 2.95 0.02 7 . 4 0 0.02 8 2 2.93 P-Lt. De osits. 22 0 0 0 .80 KER U SLI ING SLEEVE M60. 0 0.02 8 2 2.92 Pu Lt Q -- e osits. 709 0 6 2. 4 0. 13 .950 0 0 0 2.73 3.5" CAMCO D NIPPLE Penetration Body Metal Loss Body Page 5 _"--A0jbkj, KUP PROD 1D-146 w1 lvs-vrl fill" ap wenwnrlbLAOS Max An ie&MD TD Ala6xd.IRG wellb.,a apuuwi ZIT 500292352)00 WEST 3AK wa-nte s -we -fly MD Ix l act bon IRKS) PROD 0.00 16,4720 1 1., 91 S2.11 s 18',n IA1 Comment SSSV: NIPPLE I H331PPm) Oab A, a. Ead ONe KG -GN ITS RiO Rebua Ddb 110 8/122016 Last WO; 39.43 )/1]/2015 v ticelac6endk e MnoMbon Dap -V, Leal Tag: End Dad-mmuman Lut Motl By EnVD" NOV Reason: H2S, GLV CiO XPHGER', N.t i a91 ^. -' tCumOOucnption -- CaNn6 bevodp9On OO (in) CONDUCTOR 10 (In)Tep 181(8) Sat DepM IRKB)8N DePIM1 ITVp).. WYLan (I.. Good' TOP Thread welded 20 19.500 42.0 150.0 150.0 Maid; ... _. ... ............. ....... ODpnl SURFACE 10314 ... ID lin) Tap (XKBI Brt OeP-(M(bl Sa DeprM1 (rv0)... WVLan 11... GnEa TOP TM1detl 9.950 0.6 2,9810 2,5259 45.50 L 80 TSH563 CainO Deooriptlon 001-) W(inl Tap IRK6) S. Dep-IXKB) s�D.ptn ITVD1... w1a.n 0... Gt.e. TOP ThM1id IMERMEOIATE 75/e 8.8)5 38.0 ],)96.5 3,854.2 28. J0 L-00 Hytl10563 CmInO Duenptlen OD (In) LINER 412 IO lin) Top (1tl(B) 3.858 7,847,7 BeI.."m RKB) SN 11.0h TVDI... WN.en (I...G.Ea TOP 15,465,D 3,)92.9 it6O 1.80 IBT-m Thread Liner Details - - .. TO IRKB m Tv0 Wrl To ba - n.m 0.. Co. Nominnal ID cONOJC10e:416158D xRRE;ap09 7,647.7 3,041.2 84.45 PACKER BAKER HRO-E ZAP WI HD'S 4.820 7,0674 3,843.1 84.51 NIPPLE BAKER R3 NIPPLE 4.950 7,670.2 3843.4 84.52 HANGER BAKER FLEX -LOCK HANGER 4)90 GAsuR;6.Seas 7,680.1 3,844.3 84.55 XO reGueing %05.5'15.5#HytlP1563583 boabOx%5'126p Hytlri52t 4.400 Box 7,691.3 3,845.4 04.60 SBE BAKER SEAL BORE EXTENSION 4.000 7,834.4 3,856.6 86.95 SWELL TAMSWELLPACKER"F° 3.958 SURFACE; 06 .9618 PACKER 7,085.5 3,858.7 88.91 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO 3.958 CARTRIDGE 920?RACERCO)16) SN#14 GASUFL5,NS3 GAS LIFr: c..SS 8,253.6 3,883] 09.51 SWELL PACKER TAM SWELL PACKER"E' 3.958 SLEEVE 7,OAs 9,314.8 31864.0 89.83 TRACER CARTRIDGE TRAOERCO TRACER CARTRIDGE(TRACERCO 1911?RAOERC0985F) SN#13 3.858 xPRb?vs5 10,885.8 3,858,5 90.84 SWELL TAM OIL SWELL PACKER°D' 3958 PACKER cALIDE L5su9 10,746.0 3,655.8 90.6] TRACER TRACERCO TRACERCARTRIDGE(rR CERCO- 3.958 .1. CARTRIDGE 9261]RACERCO 721) SIVAS 1 USERS 3,844.0 90.22 SWELL PACKER TAM SW ELL PACKER 'C' 3.858 LOCATOR; ;5Tan 11,955.6 3,043.9 89.89 TRACER TRACER CO TRACERCARTRIDGE (TRACERCO- 3.958 CARTRIDGE 013TEACERCO 726)SN#11 13,437.5 3,819.9 90A4 SWELL TAM OIL SWELL PACKER' B' 3.958 SEX As6vpFaxx PACKER 6 13,494.5 3,818.3 90.64 TRACER CARTRIDGE TRACERCO TRACER CARTRIDGE( CERCO- 919/TRACERCO 719) SAWID 3,958 14,942.5 3,797.5 81.07 SWELL PACKER TAM OIL SWELL PACKER -A' 3.958 INTERMEOwiE seena5.5�_7 Inlemiadebm iremmeK�;• 6o20R80 15, DD25 3]966 80.]2 CARTRTRACER IDGE TMCERCOTRACERCARTRDGE(TRACERW- 920b7RACERC0465A)SN#9 3958 Tubin Strings Tubing Deaonplian sang Ma..10 TUBING -41/2'x3 312 l2" 9074 I. 2992 Top(XNB) 34.1 SO[Oep-(R.. 7,703.7 So[DapM (ry0)S.. 3,846.5 W[I-M) 8.30 r--1-Z.--TT-.1 C80 COnnec.- EUEBN Completion Details To B To D nKB To In. I Rem D.. Nominal ID cem In SLOT5;7niss 6.l4e.8-� 34.1 -JPerf0Mtjons& 0.04 MANGER VETCO GRAY HANGER WI FALSE 1331W BOWL 3.900 90,7 0.10 XO RedudR9 Crossover. 4-12'IBT mx 3-il2'EUEm 2882 493.2 288 NIPPLE CAMCO OB NIPPLE W12.0]5"PROFILE 2.975 3,]84.5 05.14 BLEEVE BAKERCMUSLIDINGSLEEVEWIDSNIPPLE 2,810 3,789.1 85.53 NIPPLE CA-C.D NIPPLE Wl 2.75 NO GO PROF ILE 2750 3,839.5 84.38 GAUGE BAKERGUARD AN GAUGE CARRIER 2.819 SOTS; P.94a 810,5607_ _� 3,043.9 8454 LOCATOR BAKERLOCATOR 950 3,845.5 84.61 $EALAS$Y BAKER GB&22 BONDED REAL ASSEMBLY 2980 s &Slots 3M1MDenTop jNO) Bin MO) esIRKS) tiK- (soma,Bon zon. mb T ],925.6 9,248.6 3,859.2 3,883.6 7/132015 SLOTS Slotted Liner sLGTsaa.P7a0�n,0ats�-_ _ 9,y14B 10,680.71 3984.0 3,856.5 7/132015 SLOTS S;z-Liner 10,7710 11,891.9 3.8554 3,844.0 T/1312D15 SLOTS 51088ELlner 11,986.) 13,432.3 3,843.9 3,819.9 )1132015 SLOTS Blptled Liner 13,524.5 14,83].3 3,019.0 3,797.8 71132015 SLOTS SlDrietl Llner 15,032.6 16,455.3 3,796.1 3,7930 )/13/2015 SLOTS ISlofted Liner _ Mandrel Inserts SLOTS: 11.9BS7-19p929� _ p IWO) we No Modal OD In Valuv Latch P.As ue TRO Run So T a T.. m Run Ofn Com 2,402.4 CA MMG 112 GASLIF1 GLV RK 0180 1,191,0 35201]3,288.3 CAMCO MIdG it2 GAS LIR OMY RK 003,)05.4 DAVID "AMG till l & SafetySLOTS; 13.524.5.14,a73T - on OTE: r SLOTS.15092o-1S4551�_ 1i __ LINER:7o47 T't5pd5.O�� ` • i 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. st21 14- - 1 37 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ;17s: Grayscale Items: s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: D-1/5— ��BY: )ariaDate: d -- /s/ VJiP Project Proofing BY: Maria Date: 149.0..ap..5-1 /s/ Scanning Preparation 7 x 30 = a. 1 0 + l O = TOTAL PAGES Q.5)...? BY: Date: D. /.5— (Count does not include cover sheet) y/1 Production Scanning Stage 1 Page Count from Scanned File: aa / (Count does include co r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: - Date: I a, g..)....//5- /s/ kg J 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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V Oas Z ii - U 112 cn Q O o N c J a m 0 1 J as dv E ' Q � 0 7 1 0in 0 0 0. inO 111 N a M p I w r, V `' 0 CD �I/^�\`�' m o T i E C E i mr o ea coE I— P E F LoO u` C z N @ c r ,H 11 c 0 ai E CO o 1— E I1 m c N m (n m 0m G Y m _�73 U a Q o a o m ilkco co LI W I o fR= Z aoi N Y W m Q: C CV O m 0 0 ui c m o ccoo Q o o Q o 0 0 c I c U '� to m a m Tx 0 o a a m u E a 0 E 0 ,..,r4OLL E o o E m ai E E 0 a 2 z 0 a c0 0 0 cC o 0 � • • Guhl, Meredith D (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Tuesday, November 03, 2015 2:50 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA); Haggerty-Sherrod, Ann (Northland Staffing Services) Subject: RE: KRU 1D-146, PTD 214-139, Complete list of Geologic Markers Meredith, please find the revised formation tops for 1D-146 below. 1D-146 Name MD TVD Top Permafrost Surface Surface Base Permafrost 1677 1637 Ugnu B 5362 3347 West Sak D 7581 3835 TD in West Sak D 16472 3793 If there are any questions,concerns, or additional information needed, please don't hesitate to contact me. Thank you, Kelsey Hallford ATO 1578 Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsev.hallfordcop.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: 30 October 2015 15:07 To: Hallford, Kelsey Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 1D-146, PTD 214-139, Complete list of Geologic Markers Kelsey, During a review of the 10-407 form submitted for KRU 1D-146, PTD 214-139, completed 7/7/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Top and Base of the West Sak sand are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by November 13, 2015. If you have any questions, please contact me. 1 • Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 REIPEIVED • 21 41 39 AUG 202015 26 070 AOGCC Transmittal#: 20AUG15-SP02 SchlumbergerDrilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery �6 24/2015GE Fal. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-146 Date Dispatched: 20-Aug-15 Job#: 15AKA0092 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A -------4-- - - LAS Digital Data N/A Contents on CD N/A Directional Data N/A Contents on CD N/A Nad27 - i-evised txt files only** x As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosoconocophillips.com AlaskaPTSPrintCenter(Cv.slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: vQ:� � }Lys^`G n ��/l �✓- ) e`�/p"J(y R C WED STATE OF ALASKA 0 AUG 17 201 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN[A[;CC_. 1 a.Well Status: Oil ❑✓ Gas❑ SPLUG ❑ Other ❑ Abandoned H Suspended❑ 1 b.Well Class: 20AAc 25.105 20AAC 25.110 Development E• Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. . Aband.: •7/17/2015 214-139 3.Address: 7. Date Spudded: 15.API Number: P. 0. Box 100360,Anchorage,AK 99501 •6/22/2015 50-029-23527-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 312'FNL,419'FEL,Sec.23,T11 N, R10E, UM •7/9/2015 KRU 1D-146 . Top of Productive Interval: 9. KB(ft above MSL): •106.5' 17. Field/Pool(s): 1173'FSL,787'FEL,Sec. 13,T11 N, R10E, UM GL(ft above MSL): •67' Kuparuk River Field/West Sak Oil Pool• Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2039'FNL,4262'FEL,Sec. 30,T11 N, R11 E, UM 16465'MD/3793'TVD ADL 25650,28248,28243 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 560671 y- 5959354 Zone- 4 '16472'MD/3793'TVD ALK 468, 591 TPI: x- 565569 y- 5960880 Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 567149 y- 5952403 Zone- nipple @ 493'MD/493'TVD 1677'MD/1637'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Temperature Log 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 154# X-52 42' 118' 42' 118' 24" 120 sx AS I 10.75" 45.5# L-80 40' 2961' 39' 2526' 13.5" 1234 sx Class G, 194 sx Class G 7.625" 29.7# L-80 39' 7797' 39' 3854' 9.875" 791 sx Class G 4.5" 11.6# L-80 7648' 16465' 3841' 3793' 6.75" slotted liner 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 7704' 7648'MD/3841'TVD slotted liner: 7926'-9249'MD/3859'-3864'TVD and 9345'-10681'MD/3864'- 3857'TVD and 10776'-11892'MD/3855'-3844'TVD amd 11986'-13432'MD/ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 3844'-3820'TVD and 13525'-14937'MD/3819'-3798'TVD and 15033'-16455' Was hydraulic fracturing used during completion? Yes❑ No ❑✓ MD/3796'-3793'TVD (4444.4.4". Iltaiikril Per 20 AAC 25.283(i)(2)attach electronic and printed information -� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED • �M._ . none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ••-.0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -I. Form 10-437 Revise 5,01,5_ j/% .. /0/2,O//5 CONTINUED ON PAGE 2 Submit ORIGINIAL only _ rKA 10 1672-0,-- RBDMS-Ak A1►0 1 9 2015 28. CORE DATA Conventional Core Yes ❑ No ❑ Sidewall Cores: • ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1677' 1637' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top West Sak Sand 7581' 3835' Base West Sak Sand 16472' 3793' Formation at total depth: West Sak 31. List of Attachments: Summary of Daily Operations,directional survey,schematic,cement reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelsey Hallford @ 265-1577 Email: Kelsey.Hallford(a)cop.com . Printed Name: Graham L.Alvord� �tTitle: Alaska Drilling Manager Signature: /L& 2( Phone: 265-6120 Date: 6(1112.0.6-- INSTRUCTIONS (t'i(2o•SINSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • • Guhl, Meredith D (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Tuesday, November 03, 2015 2:50 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA); Haggerty-Sherrod,Ann (Northland Staffing Services) Subject: RE: KRU 1D-146, PTD 214-139, Complete list of Geologic Markers Meredith, please find the revised formation tops for 1D-146 below. 1D-146 Name MD TVD Top Permafrost Surface Surface Base Permafrost 1677 1637 Ugnu B 5362 3347 West Sak D 7581 3835 TD in West Sak D 16472 3793 If there are any questions, concerns, or additional information needed, please don't hesitate to contact me. Thank you, Kelsey Hallford ATO 1578 Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallfordcop.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: 30 October 2015 15:07 To: Hallford, Kelsey Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 1D-146, PTD 214-139, Complete list of Geologic Markers Kelsey, During a review of the 10-407 form submitted for KRU 1D-146, PTD 214-139, completed 7/7/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Top and Base of the West Sak sand are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by November 13, 2015. If you have any questions, please contact me. • • Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 i KUP PROD 1D-146 ConocoPhillips , Well Attributes Max Angle&MD TD Alaska,ino ,,' Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) <oPtnMp..I 500292352700 WEST SAK PROD 0.00 16,472.0 orro••• Comment 625(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-146,8/6/201510:07:38 AM SSSV:NIPPLE Last WO: 39.43 7/17/2015 rn Vertical schematic(actual) - -Annotation Depth(ftKB) End Date Annotation Last Mod By End Date a. --- - Last Tag: Rev Reason'NEW WELL smsmith 8/3/2015 HANGER 34.1 im 1.1 asing rings , , , ,,, ,, , , , iri re. .t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 11011 CONDUCTOR 20 16.500 42.0 158.0 158.0 154.19 X52 welded Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 -0.6 2,961.0 2,525.9 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.675 38.8 7,796.5 3,854.2 29.70 L-80 Hydri1563 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 7,647.7 16,465.0 3,792.9 11.60 L-80 IBT-m ( Liner Details CONDUCTOR;42.0-158.0 ° Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) NIPPLE;493.3 �a. 7,647.7 3,841.2 84.45 PACKER BAKER HRD-E ZXP W/HD'S 4.920 GAS LIFT;2,688.3 7,667.4 3,843.1 84.51 NIPPLE BAKER RS NIPPLE 4.950 7,670.2 3,843.4 84.52 HANGER BAKER FLEX-LOCK HANGER 4.790 7,680.1 3,844.3 84.55 XO reducing XO 5.5"15.5#Hydril 563 box X 5"12.68 Hydril 521 4.400 Box 7,691.3 3,845.4 84.60 SBE BAKER SEAL BORE EXTENSION 4.000 SURFACE;-0.6-2,961.0 7,834.4 3,856.6 86.95 SWELL TAM SWELL PACKER"F" 3.958 GAS LIFT;5,196.2 9/■� � PACKER GAS LIFT;Q450.8 r 7,895.5 3,858.7 88.91 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 CARTRIDGE 920/TRACERCO-716)SN#14 SLEEVE;7,079.5 1 9,253.6 3,863.7 89.51 SWELL TAM SWELL PACKER"E" 3.958 PACKER NIPPLE;7,135.5 ' ' 9,314.8 3,864.0 89.93 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 GAUGE;7,630.0 CARTRIDGE 911/TRACERCO-165F)SN#13 10,685.8 3,856.5 90.64 SWELL TAM OIL SWELL PACKER"D" 3.958 PACKER 10,746.0 3,855.8 90.67 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 LOCATOR:7,676.0 CARTRIDGE 926/TRACERCO-721)SN#12 I'-- 11,896.9 3,844.0 90.22 SWELL TAM SWELL PACKER"C" 3.958 X',. PACKER 3• 7_.� 11,955.6 3,843.9 89.99 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 SEAL ASSY;7,692.2 - CARTRIDGE 913/TRACERCO-726)SN#11 'f.1 't I_t 13,437.5 3,819.9 90.44 SWELL TAM OIL SWELL PACKER"B" 3.958 '•� �'' PACKER 13,494.5 3,819.3 90.64 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 dM CARTRIDGE 919ITRACERCO-719)SN#10 INTERMEDIATE;38.8-7,796.5-t 14,942.5 3,797.5 91.07 SWELL TAM OIL SWELL PACKER"A" 3.958 PACKER - - 15,002.5 3,796.6 90.72 TRACER TRACERCO TRACER CARTRIDGE(TRACERCO- 3.958 CARTRIDGE 9201/TRACERCO-165A)SN#9 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection );[;.: TUBING-4 1/2"x 3 3 1/2 2.992 34.1 7,703.7 3,846.5 9.30 L-80 EUE8rd 1/2"@90.74 SLOTS 7,5256-9,246.6 - - Completion Details Nominal ID -sir Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.1 34.1 0.04 HANGER VETCO GRAY HANGER W/FALSE 13 3/8"BOWL 3.900 90.7 90.7 0.10 XO Reducing Crossover,4-1/2"IBT-m x 3-1/2"EUE-m 2.992 493.3 493.2 2.98 NIPPLE CAMCO DS NIPPLE W/2.875"PROFILE 2.875 slii i 7,079.5 3,794.5 85.14 SLEEVE BAKER CMU SLIDING SLEEVE W/DS NIPPLE 2.810 7,135.5 3,799.1 85.53 NIPPLE CAMCO D NIPPLE W/2.75 NO GO PROFILE W/RHC 2.750 SLOTS;9,344.8-10,680.7 _ (GKP) 7,630.0 3,839.5 84.39 GAUGE BAKER GUARDIAN GAUGE CARRIER 2.919 7,676.0 3,843.9 84.54 LOCATOR BAKER LOCATOR 2.950 7,692.2 3,845.5 84.61 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSEMBLY 2.980 Perforations&Slots Shot Dens SLOTS;10,776.0-11,891.9 Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 7/13/2015 7/13/2015 7/13/2015 7/13/2015 7/13/2015 t) Type Com 7,925.6 9,248.6 3,859.2 3,863.6 SLOTS Slotted Liner 9,344.8 10,680.7 3,864.0 3,856.5 SLOTS Slotted Liner 10,776.0 11,891.9 3,855.4 3,844.0 SLOTS Slotted Liner 11,985.7 13,432.3 3,843.9 3,819.9 SLOTS Slotted Liner 13,524.5 14,937.3 3,819.0 3,797.6 SLOTS Slotted Liner SLOTS Slotted Liner Valve Latch Port Size TRO Run 15,032.6 16,455.3 3,796.1 3,793.0 7/13/2015 SLOTS;11,985.7-13,432.3 Mandrel Inserts St ati on Top(ND) N Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com 2,688.3 2,402.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/16/2015 2 5,196.2 3,268.3 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 7/16/2015 3 6,450.8 3,705.4 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 7/16/2015 DCR- SLOTS;13,524.5-14,937.3 1 Notes:General&Safety End Date Annotation NOTE: -J;1'.- SLOTS;15,032.6-16,455.2 1 I LINER:7,647.7-16,485.0 e` • Time Log & Summary ConocoI'hillips Wefview Web Reporting Report Well Name: 1D-146 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 6/20/2015 12:00:00 PM Rig Release: 7/17/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase` Code Subcode T Comment 06/19/2015 24 hr Summary Move rig from maintenance @ 1Y pad to 1D-146 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Separate pipeshed from sub, install pump room booster cylinder and spare tire. Latch casing shed to sow and stage on 1Y pad. Put pump complex and pits on suspension, stage pump complex on corner of pad with sow. Hook up pits and motor shed to trucks and stage at entrance of pad for move. SIMOPS- Complete installation of starting head,diverter tee and 28'diverter line at 1D-146. 06:00 07:00 1.00 0 0 MIRU MOVE MOB P Hook up jeep to pits,stomper pipe shed back and begin 50'turn. Hook up jeep to sub and stomper to stage area. 07:00 08:30 1.50 0 0 MIRU MOVE MOB T Waiting on Kuparuk DTH to set mats on road. 08:30 12:00 3.50 0 0 MIRU MOVE MOB P Move motor complex and pump complex off 1Y to 1D pad,arrive on 1D @ 10:30. Depart 1Y with pits and pipeshed @ 11:30. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Pipe shed and pit modules on 1D pad @ 13:00 hrs, stage on pad and disconnect trucks. Return trucks to 1Y. 14:00 16:30 2.50 0 0 MIRU MOVE MOB P Connect trucks to sub and casing complex,depart 1Y pad @ 14:30 to 1D pad. Unload and lay mats for spotting sub. Lay herculite for cellar, arrive 1D pad @ 16:45 hrs. 16:30 20:00 3.50 0 0 MIRU MOVE MOB P Continue to lay mats for sub and pipe shed. Stage sub with trucks near 1D-146, disconnect truck and remove jeep from sub. Spot, shim and level sub over 1D-146 with stompers. SIMOPS-Remove upper DS hydraulic pin cyclinder from sub. Welder heat and straighten pad eyes for same. Stage pits and pump mods near sub with trucks. 20:00 22:00 2.00 0 0 MIRU MOVE MOB P Continue laying mats for pipe shed, remove lower ODS hydraulic pin cylinder on sub and replace.Walk pits into sub, pump module into pits and shim level. Page 1 of 31 Time Logs lb Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Stage pipe shed onto mats with truck adjacent sub. Disconnect trucks and walk pipeshed into sub. Lay mats for power module. 06/20/2015 Continue to spot modules,shim and set. Perform rig acceptance checklist and accept rig @ 12:00 hrs. Continue rigging up, prep drill pipe in shed for P/U. 00:00 04:00 4.00 0 0 MIRU MOVE RURD P Continue shimming complexes,spot pipe shed and pin. Spot casing shed. 04:00 05:00 1.00 0 0 MIRU MOVE RURD P PJSM, prep derrick and raise. SIMOPS-continue hooking up innerconnect lines. 05:00 05:45 0.75 0 0 MIRU MOVE RURD P PJSM, prep floor and skid rig floor. SIMOPS-continue hooking up innerconnect lines, lowering stairs on complexes. 05:45 06:30 0.75 0 0 MIRU MOVE RURD P PJSM, Lower C-section, install cushions. SIMOPS-Continue hooking up innerconnect lines 06:30 08:00 1.50 0 0 MIRU MOVE RURD P PJSM, Raise cattle chute, install covers, raise back cattle chute, lower back hatch cover. 08:00 09:30 1.50 0 0 MIRU MOVE RURD P Check Gen E-stops. Swap power over from cold starts to 3516 gen. Lower cellar and shim. 09:30 10:30 1.00 0 0 MIRU MOVE RURD P PJSM, prep derrick to scope, bridle up. 10:30 11:30 1.00 0 0 MIRU MOVE RURD P Scope derrick up and bridle down. 11:30 12:00 0.50 0 0 MIRU MOVE SFTY P Pre-spud meeting with both crews, Tool Pusher, Co Rep and Drilling Engineer. Rig accept @ 12:00 hrs. 12:00 15:00 3.00 0 0 MIRU MOVE RURD P Finish bridle down removing yokes and securing bridle lines. P/U and R/U rig tongs, make up Kelly hose to top drive and secure. Secure derrick moving straps, come-a-longs and securing SRL's,derrick climber and geronimo line. Secure cellar and install berm. Continue welding project in pit-sub innerconnect. M/U hoses and innerconnects. 15:00 19:00 4.00 0 0 MIRU MOVE RURD P Pull PS-21 slips, P/U 17'-21'/4" surface riser, N/U same atop diverter tee. N/U surface annular on riser and torque connections. Function test all pipe shed equipment and skate. Perform derrick inspection, hook up choke hose in pit innerconnect. SIMOPS-Fill MP#1 and 2 with new gear oil. Load, strap and tally 78 jts 5"DP in casing shed. Page 2 of 31 Time Logs11111 S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 0 0 MIRU MOVE RURD P N/U flow box, flow line,jet lines. Connect Koomey lines to surface annular and knife valve, install 3"to 4"swedges and 4"ball valves on starting head in cellar. Load, strap and tally 4"DP in casing shed. Bring on Drillplex mud in pits. SIMOPS- Install injection line section and new hose in pump room. 06/21/2015 Perform diverter function and accumulator test,witness waived by AOGCC Lou Grimaldi. P/U 99 stands 4" DP and 26 stands 5" DP. Perform divert shallow gas and rig evac drill. Install flow nipple, prep to P/U BHA. 00:00 05:00 5.00 0 0 MIRU MOVE RURD P Continue working 4"drill pipe in casing shed, remove kelly hose and re-route manrider cable. Misc MP2 work orders, continue P/U handling equipment, chain off 4"kill line, plug kill line in BOP deck. Conduct pre-spud derrick inspection.Top off top drive with Hydraulic/Gear oil. Bring on third load Drillplex mud into pits. 05:00 05:30 0.50 0 0 MIRU MOVE BOPE P Conduct diverter function and accumulator test,Witness waived by AOGCC Lou Grimaldi.Annular closing time=34 sec, Knife valve opened=14 sec. 3000 psi initial pressure,2125 psi after functioning. 200 psi attained=11 sec with two electric pumps, full system recovery=48 sec with two elec and two air pumps. 6 bottle N2 average=2000 psi. SIMOPS- Continue proccessing drill pipe in casing shed. 05:30 12:00 6.50 0 0 MIRU MOVE PULD P PJSM-Pick up 4"drill pipe stands (45 stands). SIMOPS-Continue assembling dog collars, collar slips. Work on fold down landing in cellar. SIMOPS-Tested rig gas alarms and PVT sensors. 12:00 17:00 5.00 0 0 MIRU MOVE PULD P Continue picking up 4"drill pipe stands 1x1 (38 stands). SIMOPS- Assemble handling equipment post annual inspection, continue working on landing in cellar, install winch on mount on rig floor. 17:00 17:30 0.50 0 0 MIRU MOVE SVRG P Service and inspect ST-80 and pipe shed hydraulics. 17:30 21:00 3.50 0 0 MIRU MOVE PULD P C/O elevators and slip inserts, build stands 5"drill pipe for total 26 stands. SIMOPS-Clean and charge pumps#1 and#2. Page 3 of 31 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 0 0 MIRU MOVE PULD P Continue building stands 4"drill pipe, (16 stands for 99 total picked up). SIMOPS-paint new handrail and step installed in pits. SIMOPS-Quadco repair connection to pit module for PVT 23:00 23:30 0.50 0 0 MIRU MOVE SFTY P Hold divert shallow gas and rig evacuation drill with CPAI Co rep, Doyon crew, MI, SLB, Gyrodata, ASRC truck drivers, CPAI pad operator.Tested abandon rig alarm, Evacuate to primary muster area @ rig shop. Post drill discussion-roles and responsibilities, shallow gas indicators, muster areas and wind sock locations. Diverter fuctioned= 0:50, Pumps on=2:10, total response time to muster area=4:45. 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Install flow nipple and air up boots, strap 5"HWDP. 36/22/2015 P/U HWDP and flex collars. Perform shallow gas and rig evac drill with night crew. M/U BHA#1 and spud to 248'MD. M/U BHA#2,drill 13%z"surface hole taking gyro surveys per program to 820' MD. 00:00 02:30 2.50 0 0 MIRU MOVE BHAH P P/U 5"HWDP build 5 stands plusl jar stand, rack back in derrick. P/U flex collar stand and rack back. Continue picking BHA components to rig floor. C/O slip inserts. 02:30 03:00 0.50 0 0 MIRU MOVE SEQP P Calibrate block height Amphion, MWD and Totco. Grease top drive and blocks. 03:00 03:30 0.50 0 0 MIRU MOVE SFTY P Hold divert shallow gas and rig evacuation drill with CPAI Co rep, Doyon crew, MI, SLB, Gyrodata, ASRC truck drivers, CPAI pad operator.Tested abandon rig alarm, Evacuate to primary muster area @ rig shop. Post drill AAR-roles and responsibilities, shallow gas indicators, muster areas and wind sock locations. Diverter fuctioned= 0:22, Pumps on=1:13, total response time to muster area=4:16. 03:30 04:45 1.25 0 0 MIRU MOVE SEQP P Conduct annual high pressure hose test and surface lines. Fluid pack all lines,test to 5000 psi for 10 minutes charted. Blow down surface equipment. 04:45 09:00 4.25 0 0 MIRU MOVE BHAH P PJSM, P/U BHA#1 per SLB DD/MWD to 98'MD. Orient motor, MWD, UBHO sub. Rig up Gyrodata. 09:00 09:15 0.25 0 98 MIRU MOVE CIRC P Obtain drilling parameters, fluid pack all lines and stage pumps up to 450 gpm, 350 psi, 35%flow out, P/U=56k, S/O=59k, ROT=57k. 09:15 09:45 0.50 98 158 MIRU MOVE DRLG P Clean out conductor from 98'to 158' MD,450 gpm, 375 psi, 34%flow out, 30 rpm, Page 4of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:00 1.25 158 248 SURFA( DRILL DDRL P Drill 13W surface hole from 158' MD , to 248'MD, 250'TVD,450 gpm, 375 psi, 34%flow out, 30 rpm,5-6k TO, 8k WOB, P/U=56k, 5/0=58k, ROT=57k.AST=.00,ART=0.60, ADT=0.60,Total bit hrs=0.60. 11:00 12:00 1.00 248 248 SURFA( DRILL BHAH P POOH from 248'MD. Swap out to BHA#2 per SLB DD/MWD. Orient UBHO sub and mud motor, carrying scribe up. 12:00 12:15 0.25 194 194 SURFA( DRILL BHAH P Continue to M/U BHA to 194'MD, Kelly up HWDP stand#!. 12:15 12:30 0.25 194 248 SURFA( DRILL REAM P Break circulation and wash down from 194'@ 300 gpm, 300 psi,24% Flow. Unable to work past obstruction/fill @ 200' MD.Wash and ream from 194'MD to 248'MD @ 452 gpm, 575 psi,40%flow out, 30 rpm, 3k TQ. 12:30 12:45 0.25 248 248 SURFA( DRILL REAM T Unable to work past obstruction/fill @ 200' MD.Wash and ream from 194' MD to 248' MD @ 452 gpm, 575 psi,40%flow out, 30 rpm, 3k TQ. 12:45 13:45 1.00 248 320 SURFA( DRILL DDRL P Directional drill 13W surface hole from 248' MD to 320'MD, 320'TVD, 450 gpm, 570 psi,40%flow out,40 rpm, 2k TQ, 8k WOB, P/U=68k, 5/0=73k, ROT=70k. 13:45 15:00 1.25 320 320 SURFA( DRILL SRVY P Lay down double from HWDP stand #2, perform gyro survey. 15:00 16:00 1.00 320 378 SURFA( DRILL DDRL P P/U double and drill from 320' MD to 378'MD above parameters. 16:00 16:30 0.50 378 378 SURFA( DRILL SRVY P Gyro survey, POOH from 378'MD to 285'MD, rack back stand and M/U jar stand.Wash down to 378' MD @ 427 gpm,440 psi, 38%flow out. 16:30 00:00 7.50 378 820 SURFA( DRILL DDRL P Directional drill 13'/2"surface hole from 378'MD to 820'MD, 818'TVD, 601 gpm, 1020 psi,43%flow out,60 rpm, TQ on/off 2k/1 k, 12k WOB, P/U=84k, 5/0=85k, ROT=85k. ADT=6.24,AST=3.44,ART=2.8. Total bit hrs=6.84,Total jar hrs=24.22 06/23/2015 Drill 13 1/2"surface hole from 892'MD to 2,477'MD. 00:00 06:00 6.00 892 1,183 SURFA( DRILL DDRL P Directional drill 13 1/2"surface hole from 892'to 1183'MD,TVD 1175'. Drill at 600 GPM, 1030 PSI, F/O 47%, RPM 60,TQ 2K,WOB 15K, OFF BTM 718 PSI, PUW 95K, SOW 93K, ROT 94K. Page 5 of 31 •Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 1,183 1,615 SURFA( DRILL DDRL P Directional drill 13 1/2"surface hole from 1183'to 1615' MD, TVD 1582'. Drill at 450 GPM, 995 PSI, F/O 41%, WOB 38K, OFF BTM 721 PSI, PUW 105K, SOW 99K, ROT 98K, TQ 1K. AST 4.07 HRS,ART.74 HRS,ADT 4.21 HRS, BIT 15.06 HRS, JARS 49.82 HRS. 12:00 18:00 6.00 1,615 2,173 SURFA( DRILL DDRL P Directional drill 13 1/2"surface hole from 1615'to 2173' MD, TVD 2050'. Drill at 650 GPM, 1520 PSI, F/O 45%,WOB 20K, RPM 60, OFF BTM 1300 PSI, PUW 112K, SOW 103K, ROT 106K, TQ 6K. 18:00 20:15 2.25 2,173 2,387 SURFA( DRILL DDRL P Directional drill 13 1/2"surface hole from 2173"to 2387' MD,TVD 2207'. Drill at 700 GPM, 1625 PSI, F/O 45%,WOB 20K, RPM 70, OFF BTM 1505 PSI, PUW 118K, SOW 103K, ROT 107K,TQ 2K. 20:15 22:30 2.25 2,387 2,387 SURFA( DRILL COND T Shakers blinding off due to tar and sand. Reciprocate pipe from 2382'to 2357'MD while changing screens on the shakers. Condition mud in the pits and vacuum mud out of the cuttings tank with vac truck while waiting on super suckers. 22:30 00:00 1.50 2,387 2,477 SURFA( DRILL DDRL P Directional drill 13 1/2"surface hole from 2387'to 2477' MD,TVD 2270'. Drill at 450 GPM, 890 PSI, F/O 34%, RPM 60, TQ 5K,WOB 17K, OFF BTM 765 PSI, PUW 120K, SOW 100K, ROT 109K,TQ 3K. AST 4.60 HRS,ART 1.79 HRS,ADT 6.39 HRS, BIT 20.85 HRS, JARS 56.21 HRS. 06/24/2015 TD 13 1/2"surface hole at 2,971'. Back ream out of the hole to the HWDP laying down 5" DP. Lay down the BHA per DD. Perform 10 3/4"hanger dummy run. Rig up to run 10 3/4"casing. 00:00 06:00 6.00 2,477 2,835 SURFA( DRILL DDRL P Drill 13 1/2"surface hole from 2,477' to 2835' MD, 2,486'TVD. Drill at 700 GPM, 1,493 PSI,42%F/O, 70 RPM, 6-7K TQ, 10K WOB, OFF BTM 1,472 PSI, PUW 135K, SOW 95K, ROT 110K, 5-6K TO. 06:00 08:30 2.50 2,835 2,971 SURFA( DRILL DDRL P Drill 13 1/2"surface hole from 2835' to 2,971'MD, 2,528'TVD. Drill at 700 GPM, 1,497 PSI,43% F/O, 70 RPM, 6-7K TQ, 15K WOB, OFF BTM 1,470 PSI, PUW 128K, SOW 98K, ROT 108K.AST 1.02,ART.99,ADT 2.01, BIT HRS 25.68, JARS 60.44. 08:30 09:30 1.00 2,971 2,971 SURFA( CASING CIRC P Pump 53 bbl nut plug sweep. Rack back stand#24 and CBU while reciprocating and rotating pipe,from 2,925'to 2,830'. Pump 700 GPM, 1,473 PSI,44%F/O, 5-6K TQ. Page'6 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 2,971 2,394 SURFA( CASING BKRM P Back ream out of the hole from 2,971'to 2,394'MD at drilling perameters. PUW 113K, SOW 105K. Lay down 5"DP doubles in the pipe shed. 12:00 17:30 5.50 2,394 756 SURFA( CASING BKRM P Continue to back ream out of the hole from 2,394'to 756'at drilling perameters. Monitor displacement at pit#2. 17:30 21:45 4.25 756 0 SURFA( CASING BHAH P Lay down BHA from 756'to 0'. Lay down HWDP and Jars. Stand back NM FLEX collars. Lay down remainder of BHA per DD. 21:45 23:00 1.25 0 0 SURFA( CASING RURD P Clear and clean floor. Drain the stack and prep for 10 3/4"hanger dummy run. 23:00 00:00 1.00 0 0 SURFA( CASING RURD P Pick up landing joint and perform dummy run. Rig up Volant tool, remove hanger and landing joint. X6/25/2015 Run 10 3/4"casing to 2,961'. Cement casing and land hanger. Float would not hold, pressure up to 120 psi on float and hold for 13 hrs, 500 psi compressive strength. 00:00 01:00 1.00 0 0 SURFA( CASING RURD P Continue rigging up to run 10 3/4" casing. 01:00 06:00 5.00 0 1,529 SURFA( CASING PUTB P RIH with 10 3/4"45.5#L-80 HYDRIL to 165'. Fill casing and check float (good). Condtinue running in the hole from 165'to 1529'. Fill every joint and top off every 10. Monitor displacement at pits 1 and 2. Torque all connections to 21,400 ft/lbs. 06:00 06:30 0.50 1,529 1,529 SURFA( CASING CIRC T Obstruction at 1529',establish circulation and stage pumps to 8 BPM, 237 psi, 26%F/O.Wash down past obstuction and continue to clean hole. 06:30 07:45 1.25 1,529 1,912 SURFA( CASING PUTB P Continue to RIH wiith casing from 1529'to 1912', below the permafrost. 07:45 08:15 0.50 1,912 1,912 SURFA( CASING CIRC P Circulate BU, stage pumps up to 6 BPM, 192 psi, 23%F/O. Reciprocate casing from 1912'to 1879', PUW 99K, SOW 90K. 08:15 10:45 2.50 1,912 2,919 SURFA( CASING PUTB P Continue to RIH with casing from 1912'to 2919'filling every joint and topping off every 10. 10:45 11:15 0.50 2,919 2,961 SURFA( CASING WASH P Break circulation and wash down to TD. Wash at 3 BPM, 144 psi, 21% flow. Land hanger at 2961'. 11:15 12:00 0.75 2,961 2,961 SURFA( CEMEN-CIRC P Circulate BU,stage pumps up to 8 BPM, 252 psi,24%F/O. Reciprocate casing from 2958'to 2928'. 12:00 13:00 1.00 2,961 2,961 SURFA( CEMEN'OTHR T Trucks brought out 3 loads of hot water for cement job.Water Temperature ranged from 80 degrees to120 degrees.Water should have been from 60 degrees to 72 degrees. Page7of31 Time Logs • 111 Date From To Dur S. Depth E. Depth Phase Code Subcode T, Comment 13:00 13:30 0.50 2,961 2,961 SURFA( CEMEN'OTHR T Trouble with batching cement. Trouble shoot pump and mixer. 13:30 15:15 1.75 2,961 2,961 SURFA( CEMEN'CIRC P Circulate through cement hose, stage pumps up to 7 BPM,320 psi, 25% F/O. PUW 165K, SOW 112K. 15:15 15:45 0.50 2,961 2,961 SURFA( CEMEN-SFTY P PJSM for cement job with SLB cementers,Truck drivers, rig crew and CPAI rep. 15:45 19:45 4.00 2,961 2,961 SURFA( CEMEN-CMNT P Circulate @ 7 bpm and recip 20' from 2961'to 2941'. Dowell pumped 5 bbls water,then tested to 3500 psi- good. Batch up MudPushll at 10.5 ppg with 2-1/2 gallons of red dye. Pump 45 bbls of CW-100 at 5.5 bpm. Pump 100 bbls of 10.5 ppg MudPush II with red dye, avg 5.5 bpm. Recip casing 20'. PUW 178k, SOW 124k. Load bottom plug, install with the Volant casing tool. Batch 11 ppg cement with 90°water. Pump cement at avg of 6.6 bpm at 240-260 psi. Pump 415 bbls(1234 sx) empty SLB tub for a total of 429 bbls LiteCrete cement. Recip casing 20'. PU wt 166k, SO wt 109k. Batch up LiteCrete tail cement to 12 ppg, Dowell pump LiteCrete tail cement at average of 4 bpm at150-200 psi. Sticky, landed casing on hanger at 18:46 hrs. Pumped a total of 58 bbls (194 sx). Load top plug, install with the Volant casing tool. Dowell pump 10 bbls of water to clear lines at 6 bpm,217 psi. Rig displaced cement with 9.6 ppg Drilplex mud.displace with rig pump at 8 bpm at 547 psi taking returns to the shakers, By-pass shakers to cuttings tank when red dye was seen. Slow down to 3 bpm at 407 psi after pumping 260 bbls, bumped the plug at 264 bbls, pumped(95%pump efficiency, 2637 strokes).69 bbls cement back to the pits. 19:45 20:15 0.50 2,961 2,961 SURFA( CEMEN'WOC T Floats did not hold. Hold 120 psi f/ 13 hrs, 500 psi compressive strength. 20:15 00:00 3.75 2,961 2,961 SURFA( CEMEN WOC T Remove cement line, install test pump hose and monitor casing pressure via test pump. Drain stack pumping treated cement to vac truck. Flush stack, function diverter bag and jet flowline. Clean all DEMCO valves in cement line. 06/26/2015 WOC, N/D diverter,well head and starter flange. N/U Vetco Grey adapter flange and test to 2000 psi. N/U BOPE and prep for BOPE test. Page 8 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:45 7.75 0 0 SURFA( CEMEN-WOC T WOC, continue cleaning flow line and pits after cementing. Strap and load casing into the pipe shed. Intall cellar door and replace plumbing to hydraulic slips on rig floor. 07:45 10:00 2.25 0 0 SURFA( CEMEN-RURD P R/D Volant tool, pull landing joint, bail extensions, elevators and casing equipment. Clean and clear floor. 10:00 12:00 2.00 0 0 SURFA( WHDBO NUND P N/D pitcher nipple, Joe's box, flow line and diverter. 12:00 13:00 1.00 0 0 SURFA( WHDBO NUND P N/D Vetco Grey well head and starter spool and remove dump valves. 13:00 18:00 5.00 0 0 SURFA(WHDBO NUND P N/U adaptor flange on top of conductor and valves. 18:00 18:15 0.25 0 0 SURFA(WHDBO SEQP P Test test adaptor flange seals at 2000 psi for 10 minutes. 18:15 21:00 2.75 0 0 SURFA( WHDBO NUND P N/U BOPE, pitcher nipple,flow line, kill and choke lines and Joe's box. 21:00 22:00 1.00 0 0 SURFA( WHDBO RURD P Pick up and intall Vetco Grey ware bushing, M/U test joint and test plug. 22:00 00:00 2.00 0 0 SURFA( WHDBO NUND P Continue to N/U BOP's,obtain BOP elevations.Annular 8.65', UPR 11.87', Blinds 12.25', Mud Cross 15.0', LPR 16.87'. 06/27/2015 Test BOPE, P/U 9 7/8"intermediate drilling assembly. RIH, test the 10 3/4"casing. Drill out the shoe track and 20'of new hole. Pull back into the shoe and perform a FIT. Start displacing to 9.4 LSND mud and start drilling head. 00:00 01:30 1.50 0 0 SURFA( WHDBO NUND P Fill lines and BOP stack with water. Drain BOP stack and change out seal on blind rams. Fill BOP stack with water. 01:30 05:30 4.00 0 0 SURFA(WHDBO BOPE P Pressure test BOPE to 250/3,500psi for 5/5 minutes on chart recorder, testing annular, upper 7-5/8"casing rams, blind shear rams, lower 2-1/2"x5-1/2"VBRs, choke valves 1-15, manual&auto choke, choke& kill manuals, HCR valves,4"valve on kill line,4"TIW,4"dart valve, 3-1/2" TIW, 3-1/2"dart valve, and Upper& lower IBOP.4"and 7-5/8"test joints were used. Manual operated and super choke tested to 250/2,000psi for 5/5 minutes on chart recorder. Witnessed by AOGCC Representative Johnny Hill. Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode, T Comment 05:30 06:00 0.50 0 0 SURFA(WHDBO BOPE P Perform Koomey drawdown test. Accumulator PSI=3,050 psi, Manifold=1,500 psi, System pressure1,750 psi after all functions on bottles. 200 psi attained= 17 sec with 2 electric pumps, full system pressure attained=97 sec with 2 electric and 2 air pumps.6 bottle N2 average=2,050 psi. Closing times for annular=23 sec, UPR= 18 sec, BSR= 16 sec, LPR= 17 sec, Choke HCR=2 sec, Kill HCR=2 sec. Witnessed by AOGCC Representative Johnny Hill. 06:00 07:00 1.00 0 0 SURFA( WHDBO BOPE P R/D test equipment&drain BOP stack. Install wearbushing and change out handling gear to 5". 07:00 07:30 0.50 0 0 SURFA( CEMEN-PULD P L/D 2 x stands of 5" DP racked in derrick. 07:30 11:30 4.00 0 733 SURFA( CEMEN-BHAH P P/U and RIH w/9-7/8" Intermediate Drilling BHA to 733' MD as per DD/MWD. Note:Tagged obstruction at 171'MD w/10klbs-work through several times w/no further issues. 11:30 14:30 3.00 733 2,770 SURFA( CEMEN PULD P RIH w/4"DP singles from pipe shed F/733' MD T/2,770'MD. Observe 7klbs drag at 2,770'MD. Note: Shallow test MWD tools @ 1,692'MD w/450gpm, 1,128psi, 30%flow 14:30 15:15 0.75 2,770 2,770 SURFA( CEMEN-CIRC P Circulate and condition mud w/ 294gpm, 585psi, 24%flow until even 9.5ppg MW observed in/out. 15:15 16:30 1.25 2,770 2,770 SURFA( CEMEN'PRTS P R/U for casing test.Test 10-3/4" 45.5#L-80 Hydril 563 casing to 3,000psi for 30 minutes on chart recorder w/9.5ppg MW. 3.8bbls pumped, 3.6bbls returned. R/D test equipment. 16:30 18:30 2.00 2,770 2,871 SURFA( CEMEN COCF P Wash and ream from 2,770'to 2,864' tagging cement. Increase drilling rate and drill out plug at 550 GPM, 1850 PSI, 33% F/O,60 RPM, 5K WOB, 5K TQ.Tag float collar on depth at 2,875'. 18:30 21:00 2.50 2,871 2,971 SURFA( CEMEN-DRLG P Drill out float collar and shoe track to 2,961'and 10'of rat hole to 2,971'. 21:00 21:30 0.50 2,971 2,991 SURFA( CEMEN-DDRL P Drill 20'of new hole at the same drilling perameters from 2,971'to 2,991'MD. 21:30 22:00 0.50 2,991 2,991 SURFA( CEMEN'CIRC P CBU and down link while ratating and reciprocating pipe from 2,991'to 2,915'. Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 2,910 2,910 SURFA( CEMEN-RURD P Rack back stand#24. blow down top drive and flush lines. Prep equipment for FIT/ 22:30 23:00 0.50 2,910 2,910 SURFA( CEMEN-FIT P Perform FIT, MW 9.4 ppg, TVD 2,525'. Max EMW 16.0 ppg, Min EMW 12.0 ppg. Pumped 2.4 bbls, Leak off at 525 psi. bled pressure to pits,1.2 bbls returned. EMW 13.4 Pp9. 23:00 00:00 1.00 2,910 2,910 INTRM1 DRILL SLPC P Slip and cut 72'of drilling line. 06/28/2015 Control drill 9 7/8"Intermediate hole from 2,971'to 5,567'. 00:00 01:30 1.50 2,910 2,910 INTRM1 DRILL SLPC P Finish slip and cut 75'of drill line. Service top drive and calibrate sensors 01:30 02:00 0.50 2,910 2,991 INTRM1 DRILL CIRC P RIH to 2,991'&displace 9.4ppg LSND mud to bit. Obtain SPR's with new mud. 02:00 03:00 1.00 2,991 2,991 INTRM1 DRILL DHEQ T Troubleshoot Schlumberger downhole tools-not receiving downlink. Note: DD believed it to be attributed to cold mud. 03:00 06:00 3.00 2,991 3,293 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 2,991'MD to 3,293'MD, 2,637' TVD. 650 gpm- 1,620 psi, 36%flow out, 100 rpm, Tq on/off=4k/3k. WOB=1k, ECD=9.8-10.05 ppg, P/U=95k, 06:00 12:00 6.00 3,293 3,924 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 3,293'MD to 3,924' MD, 2,833' TVD. 650 gpm, 1,620-1,938 psi, 37% flow out, 100-165 rpm, Tq on/off=4-5k/3-4k.WOB=1-4k, ECD=10.0-10.15 ppg, P/U=112k, S/O=66k, ROT=83k,ADT=8.65, Total bit/Jar hrs=8.65. 12:00 18:00 6.00 3,924 4,660 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 3,924'MD to 4,660' MD, 3,419' TVD. 650 gpm-2,235 psi, 36%flow out, 160 rpm, Tq on/off=5k/4k. WOB=6k, ECD=10.05 ppg, P/U=110k, S/O=82k, ROT=91k. 18:00 00:00 6.00 4,660 5,567 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 4,660'MD to 5,567'MD, 2,3,419'TVD. 700 gpm,2,930 psi, 37%flow out,165 rpm,Tq on/off=7k/3-6k.WOB=8k, ECD=10.22, P/U=120k, S/O=82k, ROT=84k,ADT=8.15,AST=8.15Total bit/Jar hrs=16.8. 36/29/2015 Control drill 9 7/8"Intermediate hole from 5,567'to 7,797'TD. TD well at 22:30 hrs. Page 11 of 31 Time Logs 4111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 5,567 6,420 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 5,567'MD to 6,420' MD, 3,698' TVD. 700 gpm, 3,090 psi, 39%flow out,165 rpm, Tq on/off=5k/4k. WOB=8-15k, ECD=10.37, P/U=129k, 5/0=84k, ROT=103k, 06:00 12:00 6.00 6,420 7,183 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 6,420'MD to 7,183' MD, 3,803' TVD. 700 gpm, 3,410 psi, 38%flow out,170 rpm,Tq on/off=8k/7k. WOB=15k, ECD=10.67, P/U=129k, S/O=82k, ROT=101k,ADT=7.21, Total bit/Jar hrs=24.01. 12:00 13:45 1.75 7,183 7,400 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 7,183'MD to 7,400' MD, 3,821' TVD. 700 gpm, 3,600 psi, 37%flow out,170 rpm, Tq on/off=8k/6k. WOB=15k, ECD=10.8, P/U=122k, S/0=81k, ROT=98k, 13:45 16:00 2.25 7,400 7,400 INTRM1 DRILL CIRC T Circulate, reciprocate and rotate at drilling parameters while repairing the swab and liner on#2 mud pump. 16:00 22:30 6.50 7,400 7,797 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 7,183'MD to 7,797' MD, 3,856' TVD. 700 gpm, 3,310 psi, 37%flow out,170 rpm,Tq on/off=10k/6k. WOB=15k, ECD=10.3, P/U=122k, S/O=80k, ROT=99k,ADT=6.01, Total bit/Jar hrs=30.04. TD well 7,797'at 22:30 hrs 22:30 23:45 1.25 7,797 7,797 INTRM1 CASING CIRC P Pump 40 bbl HI-VIS sweep, circulate 1.5 BU. Continue circulating while reciprocating and rotating pipe. Obtain slow pump rates and survey. 23:45 00:00 0.25 7,797 7,797 INTRM1 CASING OWFF P Monitor well for 10 minutes-Good X6/30/2015 Complete circulation and back-ream out to shoe. Circulate 4.5 BU and attempt to pull on elevators, pump at 3.5 BPM for 10 stands and begin back-reaming at drilling rates to HWDP. Monitor, static, and pull to BHA and LD same. 00:00 06:00 6.00 7,797 5,475 INTRM1 CASING BKRM P Back ream out of the hole from 7797' to 5475', 700 GPM with 3260 psi, FO 36%, 170 RPM with 6K torque. Work tight spot at 5636'with 13K torque until clear. 06:00 11:30 5.50 5,475 2,915 INTRM1 CASING BKRM P Back ream out of the hole from 5475'to 2915'(in shoe), 700 GPM with 2360 psi, FO 36%, 170 RPM with 6K torque. Crew change. No losses for tour. 11:30 12:00 0.50 2,915 INTRM1 CASING SFTY P Safety Stand Down for both crews at crew change. 30 minutes discussing the Wicker, Hand Injury and why it is so important to report all injuries immediately to your supervisor. Page 12 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:45 1.75 2,915 2,820 INTRM1 CASING CIRC P Circulate, rotate and reciprocate with 60 RPM and 700 GPM with 2215 psi, 38%FO, 3K torque, for 1147 BBLs. 13:45 14:15 0.50 2,820 2,820 INTRM1 CASING SVRG P Service and inspect topdrive. 14:15 16:00 1.75 2,820 1,966 INTRM1 CASING TRIP P Pull on elevators from 2820'to 1966' with hole starting to swab.decision to pump out at 3.5 BPM. 16:00 16:30 0.50 1,966 1,966 INTRM1 CASING PMPO P Decision to pump out at 3.5 BPM with pressure building. Decision made to pump a BU to clear casing. 16:30 19:00 2.50 1,966 1,966 INTRM1 CASING CIRC P Circulate a BU at 700 GPM with 1950 psi, 36% FO, 19:00 19:30 0.50 1,966 733 INTRM1 CASING TRIP P Blow down top drive and POOH from 1208'to 733'. 19:30 19:42 0.20 733 733 INTRM1 CASING OWFF P Monitor well for 10 minutes; Static 19:42 21:00 1.30 733 178 INTRM1 CASING TRIP P POOH racking back HW, LD jars to 178'. Good displacement for trip. 21:00 22:00 1.00 178 0 INTRM1 CASING BHAH P Break down and LD BHA per DD and MWD. 22:00 23:00 1.00 0 0 INTRM1 CASING BHAH P Clean and clear floor of BHA components and RU bail extensions, prep for running 7 5/8"casing. 23:00 00:00 1.00 0 0 INTRM1 CASING RURD P Drain stack and PU 5"test joint to pull wear ring. Pull wear ring. Crew change. 07/01/2015 Pull wear ring, perform dummy run; Good. RU and run 7 5/8"29.7#L-80 casing. Run into obstruction at 3172'and wash down at 6 BPM to 6160'. 00:00 01:30 1.50 0 0 INTRM1 CASING RURD P Continue to R/U to run casing. Drain stack, make dummy run, L/D landing joint and hanger. 01:30 03:00 1.50 0 0 INTRM1 CASING RURD P Remove Top Drive bell guide and pipe handler dies. P/U the Volant too. 03:00 03:30 0.50 0 172 INTRM1 CASING PUTB P P/U 7 5/8"Shoe track, BakerLoc shoe Joints 1-4. M/U track, TQ=14,400 FT/LBS per Tenaris thread Rep. 03:30 10:30 7.00 172 2,971 INTRM1 CASING PUTB P Run 7 5/8"HYD 563, 29.7#. L-80 Dopeless casing. M/U TQ=14,400 FT/LBS with the Volant tool from 172' to 2971'. Fill each joint on the fly and top off every 10. Run HydraForm centralizers every joint to#72, (3000'). 10:30 11:00 0.50 2,971 2,971 INTRM1 CASING CIRC P Break circulation at 2 BPM, 160 PSI. Stage up to 6 BPM, 245 PSI, 24% flow. Circulate 1160 strokes. 11:00 11:30 0.50 2,971 3,172 INTRM1 CASING PUTB P Run in the hole with 7 5/8"casing from 2941'to 3172'. 11:30 12:00 0.50 3,172 3,224 INTRM1 CASING CIRC P Started taking weight at 3172', put 15K down weight to 70K to get down, PUW 109K-124K,SOW 84K-88K. Circulate down from 3172'to 3224', 5 BPM,225 PSI, 19%flow. Page 13 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 3,224 4,396 INTRM1 CASING PUTB P Run 7 5/8"casing, pump casing down from 3224'to 4396', PUW 109K, SOW 94K, 6 BPM,280 PSI, 23%flow. 18:00 00:00 6.00 4,396 6,160 INTRM1 CASING PUTB P Run 7 5/8"casing, pump casing down from 4396'to 6160', PUW 148K, SOW 90K, 6 BPM, 280 PSI, 23%flow. 07/02/2015 Continue to wash down at 6 BPM to 7764'tag with 40K down weight. MU pups to space out and cement at 7760'. CIP at 1800. RD cement equipment. RU and test BOPE. 00:00 06:00 6.00 6,160 7,740 INTRM1 CASING PUTB P Run 7 5/8"casing from 6160'to 7740',washing down at 6 bpm,23% flow, 280 psi. 06:00 06:30 0.50 7,740 7,740 INTRM1 CASING HOSO P P/U the landing joint and VETCO GREY casing hanger. 06:30 08:30 2.00 7,740 7,764 INTRM1 CASING HOSO T Run 7 5/8"casing from 7740'to 7764',washing down at 6 bpm,420 psi,23%flow. Tag and set 40K down weight. Pick up and center landing joint, came back down and no go. Trouble shoot cause, could be hanger hanging up on BOP's. PUW 169K, SOW 89K. 08:30 08:45 0.25 7,764 7,764 INTRM1 CASING SFTY T PJSM for hole trouble and planning for mitigation. 08:45 12:30 3.75 7,764 7,740 INTRMI CASING CIRC T P/U joint#206 and attempt circulate and rotate down past 7764', no go. Pick back up and set 40K down weight, no go. Circulate at 7 bpm, 450 psi,22%, PUW 169K, SOW 88K. Crew change 12:00 12:30 14:30 2.00 7,740 7,760 INTRM1 CASING HOSO T L/D joint#206 an joint#191. P/U 2 pup joints: 9.85'and 4.84'. M/U landing joint and hanger. 14:30 15:00 0.50 7,760 7,760 INTRM1 CEMEN-CIRCP Circulate and condition mud for cement job. Blow down top drive and RU through cement hose. 15:00 15:15 0.25 7,760 7,760 INTRM1 CEMEN'SFTY P PJSM with SLB, rig crew, Vetco GE, GBR, and Co rep.to discuss cement procedure. Continue to circulate during meeting. 15:15 15:45 0.50 7,760 7,760 INTRM1 CEMEN-CIRCP Circulate an condition mud at 7 BPM with 450 psi, 23% FO. PU= 171K, SO=88K. Pump with SLB 5 BBLs of CW100 to PT lines. 15:45 16:00 0.25 7,760 7,760 INTRMI CEMEN-SEQP P Pressure test SLB cement lines to 1500/3500 psi; Good. Page 14 of 31 Time Logs • . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 7,760 7,760 INTRM1 CEMEN-CMNT P SLB Pump 35.1 BBLs of CW100 (40.1 BBL total)at 5.9 BPM with 470 psi,22%FO. Reciprocate string 18' off hanger. Batch and pump MudPush II 39.7 BBL of 11.5 ppg at 4.8 BPM with 320 psi, 19%FO. Break out Volant tool and drop Bottom plug at 16:11 hours. Engage Volant tool and batch 15.8 PPG cement. Pump 163.1 BBL(789 Sx at 1.16 yeild)cement at 5.7 BPM with ICP=420 psi, FCP=201 psi, 22%FO average. Drop Top plug at 16:51 hours. Pump 10 BBL water to clear lines and swap to Rig pumps. Chase Cement with 9.4 ppg mud at 6 BPM with ICP= 127 psi, FCP=695 psi. Slow to 4 BPM at 330 BBLs away,then slow to 3 BPM at 332 BBLs away. Bump plug with 3365 strokes; 339 BBL, increase pressure to 1200 psi and hold until lined up to measure returns. Bled off pressure and floats; Good. CIP at 18:00 hours. 18:00 19:00 1.00 7,760 0 INTRM1 CEMEN-RURD P RD cement equipment and SLB lines and hoses. RD Volant and GBR casing equipment. Pull landing joint and LD same. 19:00 20:00 1.00 0 INTRM1 CEMEN-WWSP P Install and test pack-off to 5000 psi for 20 minutes; Good. Witnessed by CPAI rep Paul Smith. 20:00 22:00 2.00 0 0 INTRM1 CEMEN WWWH P PU and MU wellhead washing tool and wash stack. BD and LD WW tool. 22:00 23:00 1.00 0 0 INTRM1 WHDBO RURD P RU for testing BOPE 23:00 00:00 1.00 0 0 INTRM1 WHDBO BOPE P Perform body test;good. Test BOPE to 250/3500 psi 5 min ea. on chart with 4"test joint.Witness waived by AOGCC John Crisp. Manual and super chokes tested to 250/2000 psi.With 4"test joint tested annular250/3500, valves 1, 13, 14, 15,4"kill, Upper IBOP,Test valves 2, 10, 12, HCR manual/Super chokes tested to 2000 psi. Closing times; Bag=37 sec, HCR kill=8 sec, HCR choke=9 sec. 07/03/2015 Complete BOP testing, Freeze Protect with Isotherm Surface by Intermediate annulus. PU BHA#4 and perform pipe management. Single in with 4"drill pipe. Page 15 of 31 { Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 INTRM1 WHDBO BOPE P Test BOPE to 250/3500 psi 5 minutes to chart w/4 1/2",4"&3'/2' test joints.Witness waived by AOGCC John Crisp. Manual and super chokes tested to 250/2000 psi. With 4"test joint tested annular, 2-7/8"x 5'/z'UPR,2-7/8"x 5%" LPR, Test choke valves 1-15. Test manual operated and super auto choke, manual kill, choke and kill HCR valves,4"valve on Kill line,4" TIW valve,4"Dart valve, 3'/z'TIW, 3'/2'Dart valve. Upper and Lower IBOPs. Perform Koomey test;Accumulator system pressure=3050 psi, manifold pressure= 1500 psi, Pressure after all function pumps off= 1750 psi, 200 psi recovery= 17 sec with 2 electric pumps, Full system pressure recovered=97 sec with 2 electric and 2 air pumps. Closing times; Annular=23 sec, UPR=18 sec, Blind/shears=16 sec, LPR=17 sec, Choke HCR=2 sec, Kill HCR=2 sec. 6 bottle backup N2 average=2000 psi. Crew change at 02:00. 06:00 06:30 0.50 0 0 INTRM1 WHDBO RURD P RD test equipment. 06:30 08:00 1.50 0 0 INTRM1 WHDBO RURD T Pull test plug, attempt to install 9" wear bushing without success, LD wear bushing; Stop in running tool had bad profile and would not engage/disengage properly. 08:00 08:30 0.50 0 0 INTRM1 CEMEN-SFTY P PJSM with LRS, MI rep, rig crew and CPAI rep to discuss Isotherm FP. 08:30 12:00 3.50 0 0 INTRM1 CEMEN-FRZP P Pump 10 BBLs water down OA at 0.4 BPM with 804 psi to chart. Shut in and monitor for 10 minutes. Pump 100 BBLs water down OA at 0.5 BPM with ICP=800 psi, FCP=870 psi. 0.9 BPM pump total of 109.9 BBLs pumped. SIMOPS; Install new Vetco 12 1/4" ID wear bushing, RILDS, intall 4" elevators, install PS-21 slip inserts. 12:00 14:45 2.75 0 0 INTRM1 CEMEN-FRZP P Pump 85 BBLs of Isotherm NT freeze protect, 0.75 BPM with 1000 psi down OA. SIMOPS; Xfer HWDP from ODS to DS, mobilize 4.75"production BHA 14:45 17:00 2.25 0 364 INTRM1 CEMEN-BHAH P M/U 4 3/4"Production BHA#4 to 364'. Monitor pipe displacement at pit#2. 17:00 19:00 2.00 364 1,842 INTRM1 CEMEN PULD P P/U 45 joints of 4"HWDP from 364' to 1,842'. Page 16of31 Time Logs 11111 Date From To Dur = S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 1,842 1,842 INTRM1 CEMEN-DHEQ P Shallow test MWD, 225 gpm, 1610 psi, 23%flow. (Good) 19:30 20:30 1.00 1,842 364 INTRM1 CEMEN'TRIP P POOH from 1,842'to 364'and stand back HWDP in the derrick. 20:30 00:00 3.50 364 3,012 INTRM1 CEMEN-PULD P P/U 4" DP from 364'to 3,021'. 07/04/2015 Continue to PU drill pipe and RIH with drilling BHA to 7,274'.Tag cement.test casing, and wash to the float shoe. Drill out the Shoe track and rat hole and 20'of new hole. Perform FIT(EMW 13.0 ppg). Displace well with 9.4 ppg Faze-Pro oil base mud. 00:00 02:30 2.50 3,012 7,101 INTRMI CEMEN TRIP P RIH with 4"DP from 3,012'to 7,101'. 02:30 03:00 0.50 7,101 7,274 INTRM1 CEMEN-TRIPP Conttinue to RIH from 7,101'to 7,274'. Tag cement at 7,274',WOB 10K, PUW 121K, SOW 63K. 03:00 04:30 1.50 7,274 7,196 INTRM1 CEMEN-CIRC P CBU at 220 gpm, 1380 psi, 20% flow,40 rpm, 7K TQ, PUW 121K, SOW 63K, ROT 92K. Rack back 1 stand of DP to 7,196'. 04:30 04:45 0.25 7,196 7,196 INTRM1 CEMEN-SFTY P PJSM, R/U and test casing. 04:45 05:00 0.25 7,196 7,196 INTRMI CEMEN'RURD P R/U casing test equipment. 05:00 05:45 0.75 7,196 7,196 INTRM1 CEMEN PRTS P Test casing to 3,500 psi for 30 minutes, (test good). 05:45 06:00 0.25 7,196 7,196 INTRM1 CEMEN RURD P R/D casing test equipment. 06:00 06:15 0.25 7,196 7,196 INTRM1 CEMEN-SFTY P PJSM, slip and cut drilling line. 06:15 10:15 4.00 7,196 7,196 INTRMI CEMEN-SLPC P Slip and cut drilling line twice due to bad spot in the line after the first cut. 10:15 12:00 1.75 7,196 7,669 INTRM1 CEMEN-COCF P Clean out to float collar from 7,196'to 7,669',220 gpm, 1391 psi, 15%flow, 60 rpm, 8K TQ, ROT 130K, PUW 130K, SOW 63K. 12:00 15:45 3.75 7,669 7,797 INTRM1 CEMEN DRLG P Drill out Shoe track and rat hole from 7,705'to 7,797',220 gpm, 1620 psi, 21%flow, 60 rpm, 8.0K TQ. 15:45 17:00 1.25 7,797 7,817 INTRM1 CEMEN DDRL P Drill 20'of new hole form 7,797'to 7,817', 220 gpm, 1620 psi,21%flow, 60 rpm, 8.5K TQ. Bit hrs=.75 17:00 18:00 1.00 7,817 7,792 INTRM1 CEMEN-CIRC P CBU while rotating and reciprocating from 7,817'to 7,792',220 gpm, 1600 psi,21%flow,60 rpm, 8K TQ, PUW 150K, SOW 56K. 18:00 18:15 0.25 7,792 7,792 INTRM1 CEMEN-RURD P R/U FIT test equipment. 18:15 18:45 0.50 7,792 7,792 INTRM1 CEMEN'FIT P Perform FIT, pressure to 720 psi, EMW 13.0 ppg, (successful FIT). 18:45 19:00 0.25 7,792 7,792 PROD1 DRILL RURD P R/D FIT test equipment. 19:00 19:15 0.25 7,792 7,792 PROD1 DRILL SFTY P PJSM, Faze-Pro oil base mud. 19:15 20:00 0.75 7,792 7,792 PROD1 DRILL COND P Off load LSND mud from pits to trucks. 20:00 00:00 4.00 7,792 7,792 PROD1 DRILL DISP P Displace well to 9.4 ppg Faze-Pro oil base mud,223 gpm, 1825 psi, 16% flow, 60 rpm,4K TQ, Clean pits and all circulating equipment while displacing. Page 17 of 31 Time Logs IP„ 110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 37/05/2015 24 hr Summary Clean pits and bring on remaining OBM. Drill ahead in 6 3/4”production section to 9,508'. 00:00 05:15 5.25 7,817 7,817 PROD1 DRILL DISP P Complete displacement and clean pits. Bring on OBM to complete system transfer to OBM system. SPR @ 7760'MD 3852'TVD. MW= 9.4 ppg OBM Time=0445 #1 MP-20/30 SPM with 320/580 psi #2 MP-20/30 SPM with 360/600 psi 05:15 12:00 6.75 7,817 8,329 PROD1 DRILL DDRL P Drill 6 3/4"hole from 7817'to 8329'at 250 GPM with 2340 psi, 17% FO, 130 RPM with 5K torque and 2-5K WOB. PU= 118K, SO=75K, Rot= 97K. ECD average= 10.92 ppg. ART/ADT=5.09 hours,TTL bit hours=5.09, Jar hours= 114.3 hours. Crew change. No losses for tour. OAP=300 psi. SPR @ 8225' MD 3854'TVD. MW= 9.3+ppg OBM Time= 1056 #1 MP-20/30 SPM with 420/640 psi #2 MP-20/30 SPM with 440/760 psi 12:00 18:00 6.00 8,329 8,993 PROD1 DRILL DDRL P Drill 6 3/4"hole from 8329'to 8,993' at 250 GPM with 2520 psi, 17%FO, 130 RPM with 5K torque and 2K WOB. PU= 118K, SO=75K, Rot= 97K. ECD average= 10.92 ppg. ART/ADT=4.38 hours,TTL bit hours=9.41, Jar hours= 118.62 hours. 18:00 00:00 6.00 8,993 9,508 PROD1 DRILL DDRL P Drill 6 3/4"hole from 8,993'to 9,508' at 250 GPM with 2500 psi, 17% FO, 150 RPM with 5.5K torque and 2K WOB. PU= 118K, SO=75K, Rot= 97K. ECD average= 10.92 ppg. ART/ADT=3.92 hours, TTL bit hours= 13.33, Jar hours= 122.54 hours. Crew change. No losses for day. OAP=300 psi. SPR @ 8898' MD 3858'TVD. MW= 9.4 ppg OBM Time= 1720 #1 MP-20/30 SPM with 460/690 psi #2 MP-20/30 SPM with 480/690 psi 07/06/2015 Continue to drill 6 3/4"production hole,with dilution of 100 BBL every 500 feet. Page 18 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 9,508 9,961 PROD1 DRILL DDRL P Drill 6 3/4"hole from 9508'to 9961'at 250 GPM with 2460 psi, 17%FO, 150 RPM with 6K torque and 2-8K WOB. PU= 116K, SO=73K, Rot= 97K. ECD average= 11.25 ppg. Concretions at 9586', 9793', 9961'; drill concretions with 100 RPM 6K torque and 2K WOB increasing to 8K WOB as footage is made into the concretion. SPR @ 9562'MD 3864'TVD. MW= 9.4 ppg OBM Time=0037 #1 MP-20/30 SPM with 420/660 psi #2 MP-20/30 SPM with 420/800 psi 06:00 12:00 6.00 9,961 10,607 PROD1 DRILL DDRL P Drill 6 3/4"hole from 9961'to 10607' at 255 GPM with 2500 psi, 17% FO, 150 RPM with 4K torque and 6K WOB. PU= 119K, SO=79K, Rot= 98K. ECD average= 10.92 ppg. ART/ADT=8.46 hours, TTL bit hours=21.83, Jar hours= 131.04 hours. Crew change. No losses for day. OAP=200 psi. SPR© 10030'MD 3862'TVD. MW= 9.4 ppg OBM Time=0722 #1 MP-20/30 SPM with 480/680 psi #2 MP-20/30 SPM with 520/900 psi 12:00 18:00 6.00 10,607 11,112 PROD1 DRILL DDRL P Drill 6 3/4"hole from 10607'to 11112' at 255 GPM with 2710 psi, 17% FO, 150 RPM with 7K torque and 1-3K WOB. PU= 114K, SO=80K, Rot= 97K. ECD average= 11.2 ppg. ART/ADT=3.82 hours, TTL bit hours=25.65, Jar hours= 138.68 hours. SPR @ 10701' MD 3858'TVD. MW= 9.4 ppg OBM Time= 1245 #1 MP-20/30 SPM with 520/760 psi #2 MP-20/30 SPM with 560/800 psi 18:00 00:00 6.00 11,112 11,676 PROD1 DRILL DDRL P Dri1163/4"hole from 11,112'to 11,676'at 255 GPM with 2780 psi, 17%FO, 150 RPM with 6K torque and 1-3K WOB. PU= 122K, SO= 66K, Rot=98K. ECD average= 11.2 ppg. ART/ADT=4,4 hours, TTL bit hours=30.05,Jar hours= 129.36 hours. 07/07/2015 Directionally drill the 6 3/4"production hole, maintaining mud properties and planned dilutions for ECD control. Page 19 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 11,676 12,033 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 11676' MD to 12033' MD, 3844'TVD. 255 gpm, on/off psi=2715/2710, 17%flow out, 150 rpm, TQ on/off=7k/6k, WOB=2-8k, ECD=11.15, P/U=120k, S/0=66k, ROT=97k, Drilling concretions with 100 rpm, 6-7k TQ, 2k WOB initial increase to 8k as drilled. Concretions @ 11747', 11994', 12003' MD. SPR's @ 12022' MD, 3849'TVD, 9.4 ppg, 05:30 hrs. #1-20 spm=500 psi, 30 spm=740 psi #2-20 spm=500 psi, 30 spm=720 psi 06:00 12:00 6.00 12,033 12,252 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 12033' MD to 12252' MD, 3843'TVD. 255 gpm, on/off psi=2800/2758. 16%flow out, 150 rpm, TQ on/off=7k/6k, WOB=2-10k, ECD=11.23, P/U=118k, S/0=67k, ROT=95k, Concretions @ 12042', 12101', 12140', 12192', 12251'MD. Combined tour ADT/ART=8.20, Total bit hrs=38.25, Total Jar hrs=147.46. OA pressure=250 psi 12:00 18:00 6.00 12,252 12,503 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 12252' MD to 12503' MD, 3835'TVD. 255 gpm, on/off psi=2790/2775. 17%flow out, 150 rpm, TO on/off=7k/6k,WOB=2k, ECD=11.27, P/U=120k, S/O=66k, ROT=96k. Concretions @ 12275', 12340', 12360', 12419', 12444', 12462' MD.ADT/ART=3.74, Total bit hrs=41.99, Total Jar hrs=151.2. 18:00 00:00 6.00 12,503 12,978 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 12503' MD to 12978' MD, 3828'TVD. 255 gpm, on/off psi=2900/2870. 17%flow out, 150 rpm, TO on/off=l0k/6k, WOB=2k, ECD=11.46, P/U=135k, S/0=60k, ROT=91k. Concretions© 12555', 12700', 12750', 12855', 12920', 12970' MD.ADT/ART=4.65, Total bit hrs=46.64, Total Jar hrs=155.85. SPR's @ 12598' MD, 3837'TVD, 9.4 ppg, 19:19 hrs #1-20 spm=510 psi, 30 spm=710 psi #2-20 spm=490 psi, 30 spm=710 psi OA pressure=250 psi Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 37/08/2015 24 hr summary Continue geosteering 6%production section in upper West Sak D to 15,052'MD, 3796'TVD. Managing concretion drilling to avoid doglegs, maintaining OBM and closely monitoring hole conditions.All 4"DP in hole @ 14,881' MD, drilling with 4" HWDP to TD. 00:00 06:00 6.00 12,978 13,354 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 12978' MD to 13354'MD, 3820'TVD. 252 gpm, on/off psi=2956/2950. 16%flow out, 150 rpm, TQ on/off=8k/7k, WOB=2-10k, ECD=11.56, P/U=136k, S/O=56k, ROT=100k. ADT/ART=4.00. SPR's @ 13362'MD, 3818'TVD, 9.4 ppg, 06:00 hrs #1-20 spm=520 psi,30 spm=740 psi #2-20 spm=500 psi,30 spm=760 psi OA pressure=200 psi 06:00 12:00 6.00 13,354 14,000 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 13354' MD to 14000' MD, 3814'TVD. 252 gpm, on/off psi=3020/2960. 16%flow out, 150 rpm, TQ on/off=8k/7k, WOB=2-8k, ECD=11.62, P/U=135k, S/0=55k, ROT=98k.ADT/ART= 3.99,Total bit hrs=54.63,Total Jar hrs=163.84. SPR's @ 13563' MD, 3818'TVD, 9.4 ppg, 10:45 hrs #1-20 spm=530 psi, 30 spm=810 psi #2-20 spm=510 psi, 30 spm=780 psi 12:00 18:00 6.00 14,000 14,497 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 14000'MD to 14497' MD, 3809'TVD.255 gpm, on/off psi=3050/3040. 17%flow out, 150 rpm,TQ on/off=8.5k/7k, WOB=1k, ECD=11.62, P/U=144k, S/O=48k, ROT=99k.ADT/ART= 3.56, Total bit hrs=58.46, Total Jar h rs=167.67. 18:00 00:00 6.00 14,497 15,052 PROD1 DRILL DDRL P Continue directional drilling 6%4' Production hole from 14497' MD to 15052' MD, 3796'TVD.257 gpm, on/off psi=3235/3230. 17%flow out, 150 rpm, TQ on/off=9k/7k,WOB=1 k, ECD=11.78, P/U=148k, S/O=47k, ROT=94k.ADT/ART=4.01,Total bit hrs=62.47, Total Jar hrs=171.68. SPR's @ 14592'MD,3810'TVD, 9.4 ppg, 18:55 hrs #1-20 spm=530 psi, 30 spm=790 psi #2-20 spm=580 psi, 30 spm=810 psi OA pressure=250 psi Page 21 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/09/2015 24 hr Summary Continue geosteering 6%production section in upper West Sak D to TD 16,472' MD, 3793'TVD. Circulate 10 minutes and begin backreaming out per plan to 14,121'MD. 00:00 06:00 6.00 15,052 15,555 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 15052' MD to 15555'MD, 3790'TVD.252 gpm, on/off psi=3343/3333. 17%flow out, 150 rpm, TQ on/off=8k/7.5k, WOB=2-8k, ECD=11.85, P/U=147k, S/0=47k, ROT=104k. SPR's @ 15248'MD, 3800'TVD, 9.4 ppg, 01:45 hrs #1-20 spm=600 psi, 30 spm=840 psi #2-20 spm=600 psi, 30 spm=840 psi OA pressure=250 psi 06:00 12:00 6.00 15,555 15,985 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 15555' MD to 15985' MD, 3786'TVD. 252 gpm, on/off psi=3475/3410. 17%flow out, 150 rpm,TQ on/off=10k/9k, WOB=2-10k, ECD=11.82, P/U=160k, S/0=44k, ROT=103k. ADT/ART=8.57, Total bit hrs=71.04, Total Jar hrs=180.25. 12:00 18:15 6.25 15,985 16,472 PROD1 DRILL DDRL P Continue directional drilling 6%" Production hole from 15985'MD to • TD of 16472' MD, 3793'TVD.255 gpm, on/off psi=3470/3460. 17% flow out, 150 rpm,TQ on/off=9.5k/8k, WOB=2k, ECD=11.77, P/U=161k, S/0=56k, ROT=103k.ADT/ART= 3.62,Total bit hrs=74.69, Total Jar hrs=183.9. 18:15 18:30 0.25 16,472 16,472 PROD1 CASING CIRC P Circulate at drilling rate for 10 minutes, obtain SPR's. SPR's @ 16472'MD, 3793'TVD, 9.4 ppg, 18:25 hrs. #1-20 spm=590 psi, 30 spm=-920 psi #2-20 spm=620 psi, 30 spm=920 psi 18:30 18:45 0.25 16,472 16,472 PROD1 CASING OWFF P Monitor well for 10 minutes-Static 18:45 00:00 5.25 16,472 14,121 PROD1 CASING BKRM P Backream out of hole from 16472' MD to 14121' MD @ 255 gpm, 3075 psi, 17%flow out, 150 rpm, 8.5k TQ, Start pulling @ 900 fph, increase to 1500 fph pulling speed. Monitor displacement via pits 2-4, P/U=135k, S/0=50k. 07/10/2015 Continue backreaming all stands to 7-5/8"casing shoe, circulate well clean at shoe. RBIH to TD and begin circulation prior to displacement to 9.6 ppg SFMOBM. Page 22 of 31 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 06:00 6.00 14,121 11,178 PROD1 CASING BKRM P Continue backreaming out of hole from 14121'MD to 11178'MD, 252 gpm, 2952 psi, 17%flow out, 150 rpm, 8k TQ. P/U=120k, S/0=64k, ROT=89k. Monitor displacement via pits 1-4. 06:00 12:00 6.00 11,178 8,427 PROD1 CASING BKRM P Continue backreaming out of hole from 11178' MD to 8427' MD,252 gpm,2952 psi, 17%flow out, 150 rpm, 8k TQ. P/U=115k, S/0=62k, ROT=87k. Monitor displacement via pits 1-4. 12:00 13:30 1.50 8,427 7,764 PROD1 CASING BKRM P Continue backreaming out of hole from 8427'MD to 7764'MD, 255 gpm, 2500 psi, 17%flow out, 150 rpm,4-5k TQ. P/U=117k, S/0=78k. Monitor displacement via pits 1-4. 13:30 15:00 1.50 7,764 7,764 PROD1 CASING CIRC P Circulate 2 bottoms up while R&R from 7764'MD to 7674' MD @ 255 gpm, 2500 psi, 17%flow out,60 rpm,4k TQ, Mud weight in 9.4 ppg, out 9.4+ppg.Total strokes pumped 5099, shakers cleaned up good. 15:00 15:30 0.50 7,764 7,764 PROD1 CASING SVRG P Service rig 15:30 21:45 6.25 7,764 16,472 PROD1 CASING WPRT P RIH on elevators from 7764' MD to 16472' MD filling pipe every 20 stands, Monitor displacement via pit 2. Calc Disp=62.8 bbl,Actual Disp=58.4 bbl. 21:45 00:00 2.25 16,472 16,472 PROD1 CASING CIRC P Circulate bottoms up while R&R from 16472'MD to 16442'MD @ 255 gpm, 3750 psi, 16%flow out, 150 rpm, 8k TQ, SIMOPS-Prepare pits and trucks for displacement to 9.6 ppg SFMOBM. 07/11/2015 Complete hole conditioning,displace well to 9.6 ppg SFMOBM. Flow check, drop rabbit and pump out of hole to 7764' MD. Cut/Slip, trip on elevators from 7764'to 5962'MD. Installing supersliders on liner running string. 00:00 01:00 1.00 16,472 16,472 PROD1 CASING CIRC P Continue circulate while R&R from 16472' MD to 16442'MD, 255 gpm, 3703 psi, 16%flow out, 150 RPM, 8k TQ,total pumped 10505 stks, (2 BU) 01:00 03:30 2.50 16,472 16,472 PROD1 CASING DISP P PJSM and displace well to 9.6 ppg Solids free MOBM. Start with 18 bbl HV spacer,2 bpm 761 psi. Chase with SFMOBM,stage up to 6 bpm, 3730 psi, 120 rpm,8k TQ.Adjust pump rate down to 220 gpm, 3200 psi final to keep ECD below 12.0 ppg. Page 23 of 31 Time Logs 411, 1111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:15 0.75 16,472 16,472 PROD1 CASING OWFF P Shut down pumps, clean under shakers and troughs, OWFF-static, obtain SPR's. SPR's @ 16472'MD, 3792'TVD, 9.6 ppg, 04:15 hrs #1-20 spm=800 psi, 30 spm=1200 psi #2-20 spm=820 psi, 30 spm=1200 psi 04:15 06:00 1.75 16,472 15,705 PROD1 CASING PMPO P Begin pumping out of hole from 16472' MD to 15705' MD. Pumping 3 bpm, 1300 psi, 10%flow out, 2000 fph pulling speed. 06:00 07:15 1.25 15,705 15,252 PROD1 CASING PMPO P Continue pumping out of hole from 15705'MD to 15252' MD, 3 bpm, 1300 psi, 10%flow out, P/U=140k. 07:15 08:30 1.25 15,252 14,947 PROD1 CASING PMPO P PJSM, continue pumping out HWDP from 15252' MD to 14947' MD, installing supersliders on 12 joints HWDP for liner run, rack back on drillers right. 08:30 12:00 3.50 14,947 12,876 PROD1 CASING PMPO P Continue pumping out of hole from 14947'MD to 12876'MD, 2 bpm, 780 psi, 12%flow out, P/U=129k, 3000 fph pulling speed. OA= 160 psi Losses for tour while pumping out= 15 bbl 12:00 19:45 7.75 12,876 7,764 PROD1 CASING PMPO P Continue pumping out of hole from 12876' MD to 7764' MD,2 bpm, 640 psi, 10%flow out, P/U=114k, 3000 fph pulling speed. Monitor displacement via pit 7. _ 19:45 21:15 1.50 7,764 7,764 PROD1 CASING SLPC P Cut 94'of 6 x19 EXT IMP Plow steel drill line, slip on same. Monitor well- static. Calibrate Amphion, SLB and Totco block height. Check Hi/Lo travel stops. 21:15 21:45 0.50 7,764 7,764 PROD1 CASING SVRG P Service blocks and top drive 21:45 23:30 1.75 7,764 6,247 PROD1 CASING TRIP P Trip out of hole from 7764'on elevators to 6247'MD, filling hole from pit 7, hole fill pump,good hole fill>2.5 bbl per 5 stands. 23:30 00:00 0.50 6,247 5,962 PROD1 CASING TRIP P Continue out of hole on elevators from 6247'MD to 5962' MD, installing supersliders on each joint. Monitor displacement via pit#7, good displacement>2.5 bbl/5 stands. OA= 150 psi Total mud lost for tour 17.9 bbl 07/12/2015 Continue pulling out of hole installing supersliders in liner running string, 189 sliders total. L/D BHA. P/U and run 4'/2' 11.6#IBTM slotted/12.6#blank liner with tracers and swell packers. Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:30 8.50 5,962 364 PROD1 CASING TRIP P Continue tripping out of hole on elevators from 5962' MD to 364'MD installing super sliders on every joint to stand#3. No sliders on stands 1 &2. Calc fill for trip=101.6 bbl, Actual fill for trip=128.8 bbl,Total loss for trip=27.2 bbl. 08:30 09:00 0.50 364 364 PROD1 CASING OWFF P Monitor well for flow, static. PJSM with all hands involved on laying down BHA. CHange out slip inserts from 4"to hand slip inserts. 09:00 12:00 3.00 364 0 PROD1 CASING BHAH P Rack back 1 stand HWDP for liner run on off driller side. Lay down BHA per DD/MWD to 93' MD. Flush BHA with LVT. Place all layed down pieces on elevated rack with berm to finish draining tools. 12:00 12:45 0.75 0 0 PROD1 CASING BHAH P Clean and clear rig floor. 12:45 14:00 1.25 0 0 COMPZ CASING RURD P Rig up to run 4'/2'liner,double check pipe count with BHI rep, CPAI rep and DDI driller. 14:00 14:15 0.25 0 0 COMPZ CASING SFTY P PJSM for running liner with DDI, BHI, CPAI and Doyon casing. 14:15 00:00 9.75 0 6,674 COMPZ CASING PUTB P P/U and RIH to 6674' MD with 4'/2' 11.6#L-80 IBT-M slotted liner with blanks, swell packers and tracer cartridges as per running order. Install 6-1/8" Hydroform centralizer on all slotted joints,6-1/2"Hydroform with stop ring above and below all swell packers. Swell Packer A in hole @ 17:10 hrs, Swell B @ 19:15, Swell C @ 21:20, Swell D @ 22:50 hrs. P/U=86k, S/O=73k. Monitor displacement pit 7, 0 losses. Good displacement. 07/13/2015 Continue P/U 4'/2'liner per detail,XO to drill pipe and run liner to depth and set liner hanger and liner top packer. Test packer, release and confirm. Displace well from 9.6 ppg SFMOBM to 9.6 ppg brine. 00:00 03:45 3.75 6,674 8,831 COMPZ CASING PUTB P Continue P/U and RIH from 6674'to 8831.3' MD with 4'/2' 11.6#L-80 IBT-M slotted liner with blanks, swell packers and tracer cartridges as per running order. Install 6-1/8" Hydroform centralizer on all slotted joints,6-1/2" Hydroform with stop ring above and below all swell packers. Swell Packer E in hole @ 01:10 hrs, Swell F @ 03:20. P/U=86k, S/O=73k. Monitor displacement pit 7, 0 losses. Good displacement. 03:45 04:15 0.50 8,831 8,862 COMPZ CASING PUTB P PJSM, P/U seal bore assemebly, C/O slip inserts and elevators. Page 25 of 31 Time Logs 11 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:15 05:15 1.00 8,862 8,908 COMPZ CASING OTHR P P/U and M/U liner hanger and tie-back extension. Mix and pour Pal Mix, clean and clear rig floor.XO to 4" DP. 05:15 05:45 0.50 8,908 9,021 COMPZ CASING RUNL P Run liner on drill pipe from 8908'MD to 9021' MD, P/U=98k, 5/0=70k. Establish circulation through liner hanger, packer and running tools, 3 bpm,287 psi. 05:45 11:30 5.75 9,021 16,464 COMPZ CASING RUNL P Run liner on drill pipe from 9021'MD to 16464'MD. Filled pipe @ stand #20, pumped 30 bbl @ 3 bpm,430 psi. Pipe started auto filling thereafter. Obtained rotating weight on stand#40. P/U=110k, S/O=70k, ROT=84k,TQ=4k @ 10 rpm. 11:30 12:00 0.50 16,464 16,472 COMPZ CASING HOSO P P/U single and RIH to tag bottom. RIH to 16482'to tag, P/U 10' until saw string weight,verify TD @ 16472' MD. P/U=165k, S/O=54k. Fluid lost for tour=2 bbl. 12:00 13:15 1.25 16,472 16,462 COMPZ CASING PACK P P/U to liner setting depth of 16462' MD. Drop 1.75"ball and pump down @ 3 bpm, 730 psi.At 400 stks reduce rate to 2 bpm, 490 psi. Ball on seat @ 538 stks. Pressure up to 1935 psi and slack off 30k to confirm hanger set. Increase pressure to 2630 psi and hold for 10 minutes. Increase pressure to 4200 psi to release and bleed off. P/U to confirm release with 132k P/U wt. 13:15 14:45 1.50 16,462 7,644 COMPZ CASING PRTS P R/U and test packer/IA to 3500 psi for 10 minutes charted, pumped 3.2 bbl. P/U 11'to expose dogs and rotate @ 20 rpm,4k Tq, 120k rotating weight. Slack off to 75k to confirm packer set. Re-test packer/IA to 3500 psi for 10 minutes charted (good)3.2 bbl pumped. L/D 2 singles. Liner top=7644' MD, P/U with liner=165k, S/O with liner=63k, P/U without liner=132k. 14:45 17:30 2.75 7,644 7,644 COMPZ WELLPF OTHR P Empty pits, build pills, flood and fluish tanks and lines for displacement from MOBM to 9.6 KCL/NaCL brine. Hold pre-job for displacement. Page 26 of 31 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:30 19:45 2.25 7,644 7,640 COMPZ WELLPF DISP P Displace well to 9.6 ppg brine, begin with 10 bbl LVT-200, 50 bbl weighted transition spacer, 50 bbl cleaning spacer, 40 bbl tail spacer followed by 9.6 ppg KCI/NaCl brine. 540 bbl total pumped @ 3 bpm, 550 psi, 16%flow out.With brine around corner pull above hanger, recip pipe from 7640' MD to 7560'MD increase rate to 8 bpm, 1500 psi, 19%flow out, P/U=124k, S/0=94k. Observed inordinant amount of mudstone/sand returns on shakers during displacement. 19:45 22:30 2.75 7,640 7,609 COMPZ WELLPF OTHR P Shut down and clean Joes box, flow line, mud trough, below shakers, tanks and lines. Lay down 1 single. 22:30 00:00 1.50 7,609 7,609 COMPZ WELLPF CIRC P Continue pumping per plan additional 2 bottoms up. Pumped additional 40 bbl Citric Acid spacer and 60 bbl Deepclean cleaning spacer due drill pipe and casing still oil wet. Pump spacers around @ 4 bpm for contact time,then increase rate to 8 bpm 1500 psi, 19%flow out, 9.6 ppg in/out.Total pumped 6000 stks. Reciprocated pipe 7609'-7519'MD during circulation. Shakers cleaned up significantly. Total losses for tour=0 07/14/2015 POOH, L/D 4" DP, removing supersliders. Lay down liner running tools, inspect dog sub verify ZXP set. Lay down 4"drill pipe from derrick. 00:00 00:30 0.50 7,609 7,609 COMPZ WELLPF OWFF P OWFF for 30 minutes, brine slighly out of balance but went static after 10 minutes. 00:30 06:00 5.50 7,609 4,422 COMPZ WELLPF PULD P B/D top drive, POOH on elevators, lay down 57 HWDP singles. Continue laying down singles 4"DP while removing super sliders on every joint from 7640'MD to 4422' MD. Monitor hole fill on trip tank#2. P/U=128k. 06:00 11:30 5.50 4,422 75 COMPZ WELLPF PULD P Continue POOH on elevators from 4422' MD to 75'MD laying down singles and 54 doubles racked in pipe shed tubs. Removing super sliders from every joint. Monitor hole fill trip tank#2, P/U=52k. 11:30 12:00 0.50 75 0 COMPZ WELLPF BHAH P Change out slip inserts and lay down Baker running tools per Baker rep. Verify dog sub was sheared as designed, ball on seat,shifting tool shifted. Total loss for tour 4 bbl. OA pressure=175 psi Page 27 of 31 110 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 0 0 COMPZ WELLPF RURD P Clean and clear rig floor, change out PS-21 slip inserts. 12:30 15:30 3.00 0 7,306 COMPZ WELLPF TRIP P RIH to 7306'MD, 77 stands in order to facilitate laying down singles. Monitor displacement via trip tank. 15:30 00:00 8.50 7,306 1,600 COMPZ WELLPF PULD P POOH sideways, laying down 4"DP singles from 7306' MD to 2500' MD, RIH with remaining 14 stands and continue POOH laying down 4"DP sideways to 1600'MD. Total fluid loss for tour=7 bbl. 07/15/2015 Complete laying down 4" DP, pull wear ring, R/U and run 3'/z"Completion string. Locate and P/U space out pups,41/2"jt, hanger and landing joint 00:00 01:30 1.50 1,600 0 COMPZ WELLPF PULD P Continue laying down 4"drill pipe sideways from 1600'MD to 0'. Monitor well via trip tank#2. 01:30 02:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor, prep to rig up and run 3'/z'upper completion. Double checked pipe count with Doyon, Baker and CPAI. 02:00 04:00 2.00 0 0 COMPZ RPCOM RURD T Attempt to pull wear ring unseccessful. Pull running tool and P/U stack washer, flush stack and wear ring of potential debris in profile. Vetco inspected the run/pull tool and found one alien head pin loose, keeping the tool from engaging. Tightened pin and pulled wear ring. 04:00 04:30 0.50 0 0 COMPZ RPCOM RURD P Pull 12-1/4"wear bushing. 04:30 05:30 1.00 0 83 COMPZ RPCOM PUTB P Held PJSM running upper completion 3'/z'9.3#L-80 EUE-8rd-M. P/U and RIH with Baker seal assembly,joint #1 and Centralift Guardian guage carrier. 05:30 07:00 1.50 83 83 COMPZ RPCOM OTHR P Centrialift M/U guage, TEC wire to guage and test, R/U sheave. 07:00 12:00 5.00 83 2,050 COMPZ RPCOM PUTB P RIH with upper completion 3'/2'9.3# L-80 EUE-8rd-M tubing and TEC wire from 83'to 2050'MD, installing 3%" cannon clamps on every connection, testing TEC wire every 1000'. Fluid lost for tour=3 bbl OA pressure=160 psi. 12:00 18:00 6.00 2,050 5,561 COMPZ RPCOM PUTB P Continue RIH with upper completion 3'/2'9.3#L-80 EUE-8rd-M tubing and TEC wire from 2050'to 5561'MD, installing 3'/z'cannon clamps on every connection,testing TEC wire every 1000'. Monitor displacement via trip tank. Page 28 of 31 •Time Logs Date From ;To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 22:15 4.25 5,561 7,708 COMPZ RPCOM PUTB P Continue RIH with upper completion 3'/z"9.3#L-80 EUE-8rd-M tubing and TEC wire from 5561'to 7598" MD, installing 3'/z'cannon clamps on every connection,testing TEC wire every 1000'. Monitor displacement via trip tank. Continue picking up 3%"joints 236,237,239 to 7708' MD to locate. 22:15 00:00 1.75 7,708 7,669 COMPZ RPCOM HOSO P Tag up 15'in on joint#239, 7708' MD with 10k set down on locator. Lay down joints 239-236. P/U 2.28' pup, 10.29'pup, M/U XO to 4'/z' IBT-M, 1 jt 4'/z'IBT-M,Vetco hanger and landing joint. Total 241-3'/2'Cannon clamps, 2- 4'/2'Cannon clamps. 07/16/2015 Terminate TEC wire through hanger, reverse in inhibited brine. Land tubing, RILDS.Test hanger seals,fail upper seal test. Pull hanger change seal,test good. Test IA, SOV sheared @ 900 psi. Drop ball/rod, PT annulus to 3000 psi. Bleed PSI and set BPV,test. OWFF breathing back brine for 6 hrs.After 30 min static, N/D BOP, N/U tree. 00:00 02:00 2.00 7,669 7,669 COMPZ RPCOM THGR P Clean and clear rig floor, orient and tie in TEC wire to hanger per Baker Centralift/Vetco. 02:00 02:30 0.50 7,669 7,669 COMPZ RPCOM CRIH P Rig up to reverse in corrosion inhibitor from vac truck down IA, taking returns out tubing through _ cement line. 02:30 03:30 1.00 7,669 7,669 COMPZ RPCOM CRIH T Start pumping inhibitor,shut down due leaky camlock fitting on vac truck. Replace rubber gasket and re-try. Still leaking, change out camlock fitting on truck. 03:30 05:30 2.00 7,669 7,669 COMPZ RPCOM CRIH P Continue reversing in pumped 24 bbl corrosion inhibitor,followed by 240 bbl of clean 9.6 ppg brine. Staged pumps up to 3 bpm, 300 psi, reduce rate to 2.5 bpm as pressure climbed to 400 psi @ 650 strokes. Resume displacement at 3 bpm, 300-350 psi. 05:30 05:45 0.25 7,669 7,669 COMPZ RPCOM RURD P Blow down kill line,drained BOP stack and riser. 05:45 07:00 1.25 7,669 7,704 COMPZ RPCOM THGR P Landed tubing hanger, ran in lock down screws. Rig up to test tubing hanger. 07:00 08:00 1.00 7,704 7,704 COMPZ RPCOM THGR P Test lower tubing hanger seals to 5000 psi charted for 15 minutes. 08:00 09:30 1.50 7,704 7,704 COMPZ RPCOM THGR T Attempt test on upper hanger seals multiple times and would not test. Vetco rep troubleshooting. 09:30 10:30 1.00 7,704 7,669 COMPZ RPCOM THGR T Pulled tubing hanger, R/D cement hose and back out landing joint to replace upper seal on hanger. 10:30 11:00 0.50 7,669 7,704 COMPZ RPCOM THGR T Re-landed tubing hanger, ran in lock down screws, re-rigged up to test. Page 29 of 31 Time Logs III Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 7,704 7,704 COMPZ RPCOM PRTS P Tested upper and lower hanger seals to 5000 psi charted for 15 minutes each,good tests. 11:30 12:00 0.50 7,704 7,704 COMPZ RPCOM THGR P Rig up to pump down IA with injection line to pressure test IA to 1000 psi.Attempt pressure test on IA to 1000 psi, SOV sheared out early @ 900 psi. OA pressure=180 psi Losses for tour=+-20 while pumping inhibitor and chasing. 12:00 13:00 1.00 7,704 7,704 COMPZ RPCOM WAIT T Wait on orders from ANC. R/D headpin&hoses on landing joint. P/U T-bar. 13:00 14:45 1.75 7,704 0 COMPZ RPCOM PRTS P Drop ball and rod,wait 30 minutes to fall. Pressure up on tubing and IA to 3000 psi for 30 minutes charted. Pumped 4 bbl to pressure up. R/D and L/D landing joint. 14:45 15:30 0.75 0 0 COMPZ WHDBO MPSP P Dry rod BPV and test from below to 2000 psi for 10 minutes charted. 15:30 21:30 6.00 0 0 COMPZ WHDBO OWFF T Monitor well for flow, slight flow observed. Monitor returns with vis cup, Initial time 1:11 per vis cup, reduced to 2:52 per cup. Shut in IA to monitor pressure, built 4 psi in 30 minutes. Opened up IA, bled to cellar and well went static. Observe no flow 30 minutes. SIMOPS-Rig down hole fill lines, strip-o-matic and joes box. 21:30 22:45 1.25 0 0 COMPZ WHDBO NUND P Nipple down BOPE, choke/kill lines and risers. 22:45 00:00 1.25 0 0 COMPZ WHDBO NUND P Remove hanger installation plate, fill void&nipple up adapter flange and tree. 37/17/2015 Complete N/U tree and valves. Terminated TEC wire,tested adapter void to 5000 psi. Pull BPV and set TWC, test tree to 5000 psi. Pull TWC, R/U and freeze protect with 87 bbl diesel,equalize tubing/IA. R/D and secure well. Begin moving rig to 1D-145. Rig release @ 12:00 hrs. 00:00 02:00 2.00 0 0 COMPZ WHDBOWAIT T Wait on Centrilift to arrive on location with TEC wire termination tree bonnet adapter kit. Informed that they do not install anymore.Attempt to reach CPAI Automation team, or insrumentation team to install due to incident on 1D-143. Completion engineer negotiated with Centrilift to install the penetration. SIMOPS- Install valves on IA and Tubing per Vetco, clean and clear cellar and rig floor, cleaning pits. 02:00 02:45 0.75 0 0 COMPZ WHDBO OTHR P Centrilift installed TEC wire termination. Test wire good, reading 1900 psi BHP. Page 30 of 31 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 0 0 COMPZ WHDBO PRTS P Pressure test adapter void and TEC wire penetrations to 5000 psi, CPAI witnessed. 03:00 04:15 1.25 0 0 COMPZ WHDBO MPSP P Pull BPV, set TWC. 04:15 04:45 0.50 0 0 COMPZ WHDBO PRTS P Pressure test tree to 250/5000 psi for 5 minutes each, charted. 04:45 05:00 0.25 0 0 COMPZ WHDBO FRZP P R/U to freeze protect. 05:00 07:30 2.50 0 0 COMPZ WHDBO FRZP P Pump diesel freeze protection 88.5 bbl diesel down the IA,taking returns out the tubing, 1.5 bpm 765 psi. Line up and allow tubing and IA to communicate for 30 minutes. 07:30 11:00 3.50 0 0 COMPZ WHDBO MPSP P R/U lubricator and test, set BPV. Secure well per Vetco rep. IA=300, OA=85, TBG=0. SIMOPS-Lower cattle chute, prep to scope derrick. 11:00 12:00 1.00 0 0 DEMOB MOVE RURD P PJSM to scope derrick, disconnect rig floor to pit complex. Rig released @ 12:00 7/17/15 Page31of31 S • NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-146 Definitive Survey Report 15 July, 2015 . ft • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 1D-146 Well Position +N/-S 0.00 usft Northing: 5,959,353.83 usft Latitude: 70°17'58.244 N +E/-W 0.00 usft Easting: 560,670.88 usfl Longitude: 149°30'31.111 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 67.10 usft Wellbore 1D-146 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/22/2015 18.84 80.92 57,556 Design 1D-146 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.43 Vertical Section: Depth From(TVD) +N/-S +Ei-W Direction (usft) (usft) (usft) (0) 39.43 0.00 0.00 137.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.00 466.00 1 D-146 Srvy#1 GYD-GC-SS(1 D-146) GYD-GC-SS Gyrodata gyro single shots 6/23/2015 8:2' 495.29 2,898.04 1 D-146 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 8:31 2,988.78 7,731.41 1D-146 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/24/2015 12:Z 7,823.00 16,412.21 1D-146 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/6/2015 10:4 Survey w� * Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°)'- (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100') (ft) Survey Tool Name 39.43 0.00 0.00 39.43 -67.10 0.00 0.00 5,959,353.83 560,670.88 0.00 0.00 UNDEFINED 80.00 0.16 177.50 80.00 -26.53 -0.06 0.00 5,959,353.77 560,670.88 0.39 0.04 GYD-GC-SS(1) 121.00 0.14 188.79 121.00 14.47 -0.16 0.00 5,959,353.67 560,670.88 0.09 0.12 GYD-GC-SS(1) 158.00 0.24 182.95 158.00 51.47 -0 28 -0.01 5,959,353.55 560670 87 0 27 0.20 GYD GC S$(1) 20"X 34" NOT an Actual Survey 216.00 0.39 179.66 216.00 109.47 -0.60 -0.02 5,959,353.23 560,670.87 0.27 0.43 GYD-GC-SS(1) 275.00 0.57 164.33 275.00 168.47 -1.08 0.06 5,959,352.75 560,670.95 0.37 0.84 GYD-GC-SS(1) 372.00 1.50 139.43 371.98 265.45 -2.51 1.02 5,959,351.32 560,671.92 1.04 2.53 GYD-GC-SS(1) 466.00 2.49 129.64 465.92 359.39 -4.75 3.39 5,959,349.11 560,674.31 1.11 5.79 GYD-GC-SS(1) 495.29 3.02 124.45 495.18 388.65 -5.59 4.52 5,959,348.27 560,675.44 2.00 7.17 MWD+IFR-AK-CAZ-SC(2) 588.03 4.24 115.21 587.73 481.20 -8.44 9.63 5,959,345.47 560,680.58 1.45 12.74 MWD+IFR-AK-CAZ-SC(2) 7/15/2015 10:09:41AM Page 2 COMPASS 5000.1 Build 74 III Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146 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 681.75 4.78 111.26 681.16 574.63 -11.33 16.41 5,959,342.64 560,687.38 0.66 19.47 MWD+IFR-AK-CAZ-SC(2) 776.91 5.10 105.70 775.97 669.44 -13.91 24.17 5,959,340.12 560,695.16 0.60 26.66 MWD+IFR-AK-CAZ-SC(2) 871.83 6.91 106.42 870.36 763.83 -16.67 33.71 5,959,337.44 560,704.72 1.91 35.18 MWD+IFR-AK-CAZ-SC(2) 970.63 10.80 104.09 967.97 861.44 -20.60 48.40 5,959,333.62 560,719.44 3.95 48.07 MWD+IFR-AK-CAZ-SC(2) 1,060.02 11.78 101.78 1,055.63 949.10 -24.50 65.45 5,959,329.86 560,736.52 1.21 62.56 MWD+IFR-AK-CAZ-SC(2) 1,112.51 11.50 102.87 1,107.04 1,000.51 -26.76 75.80 5,959,327.68 560,746.89 0.68 71.27 MWD+IFR-AK-CAZ-SC(2) 1,155.54 12.23 103.88 1,149.15 1,042.62 -28.81 84.41 5,959,325.70 560,755.51 1.76 78.64 MWD+IFR-AK-CAZ-SC(2) 1,250.98 14.85 104.07 1,241.93 1,135.40 -34.21 106.09 5,959,320.48 560,777.23 2.75 97.37 MWD+IFR-AK-CAZ-SC(2) 1,344.66 17.52 102.12 1,331.89 1,225.36 -40.09 131.52 5,959,314.81 560,802.71 2.91 119.02 MWD+IFR-AK-CAZ-SC(2) 1,439.69 20.51 97.07 1,421.73 1,315.20 -45.14 162.04 5,959,310.00 560,833.26 3.59 143.53 MWD+IFR-AK-CAZ-SC(2) 1,534.57 23.74 93.15 1,509.61 1,403.08 -48.24 197.61 5,959,307.19 560,868.86 3.74 170.05 MWD+IFR-AK-CAZ-SC(2) 1,628.39 27.45 88.85 1,594.22 1,487.69 -48.84 238.11 5,959,306.91 560,909.35 4.42 198.11 MWD+IFR-AK-CAZ-SC(2) 1,722.34 27.52 87.55 1,677.57 1,571.04 -47.48 281.44 5,959,308.63 560,952.67 0.64 226.67 MWD+IFR-AK-CAZ-SC(2) 1,817.50 31.97 81.11 1,760.19 1,653.66 -42.64 328.33 5,959,313.84 560,999.52 5.75 255.11 MWD+IFR-AK-CAZ-SC(2) 1,867.23 33.16 76.88 1,802.11 1,695.58 -37.52 354.59 5,959,319.18 561,025.73 5.16 269.27 MWD+IFR-AK-CAZ-SC(2) 1,912.16 33.17 75.32 1,839.72 1,733.19 -31.62 378.45 5,959,325.27 561,049.54 1.90 281.23 MWD+IFR-AK-CAZ-SC(2) 2,007.73 34.99 69.38 1,918.89 1,812.36 -15.34 429.41 5,959,341.96 561,100.35 3.97 304.07 MWD+IFR-AK-CAZ-SC(2) 2,101.57 37.97 64.91 1,994.35 1,887.82 6.39 480.75 5,959,364.10 561,151.52 4.25 323.20 MWD+IFR-AK-CAZ-SC(2) 2,197.38 39.13 62.81 2,069.28 1,962.75 32.70 534.34 5,959,390.84 561,204.89 1.83 340.50 MWD+IFR-AK-CAZ-SC(2) 2,291.79 42.43 60.59 2,140.77 2,034.24 61.96 588.60 5,959,420.54 561,258.90 3.82 356.11 MWD+IFR-AK-CAZ-SC(2) 2,387.77 44.47 59.71 2,210.44 2,103.91 94.82 645.84 5,959,453.86 561,315.87 2.22 371.11 MWD+IFR-AK-CAZ-SC(2) 2,481.16 48.90 58.56 2,274.49 2,167.96 129.70 704.14 5,959,489.19 561,373.88 4.83 385.37 MWD+IFR-AK-CAZ-SC(2) 2,574.34 51.86 58.30 2,333.91 2,227.38 167.27 765.28 5,959,527.26 561,434.71 3.18 399.59 MWD+IFR-AK-CAZ-SC(2) 2,668.73 53.77 58.19 2,390.95 2,284.42 206.85 829.22 5,959,567.34 561,498.33 2.03 414.25 MWD+IFR-AK-CAZ-SC(2) 2,764.04 59.97 56.48 2,443.02 2,336.49 249.94 896.35 5,959,610.97 561,565.10 6.68 428.52 MWD+IFR-AK-CAZ-SC(2) 2,809.43 64.01 56.25 2,464.33 2,357.80 272.13 929.71 5,959,633.43 561,598.28 8.91 435.04 MWD+IFR-AK-CAZ-SC(2) 2,858.60 65.87 55.91 2,485.16 2,378.63 296.99 966.67 5,959,658.58 561,635.03 3.83 442.07 MWD+IFR-AK-CAZ-SC(2) 2,898.04 66.55 54.06 2,501.07 2,394.54 317.69 996.22 5,959,679.53 561,664.41 4.63 447.08 MWD+IFR-AK-CAZ-SC(2) 2,961.00 67.03 53.55 2,525.88 2,419.35 351.86 1,042.92 5,959,714.07 561,710.83 1.06 453.93 MWD+IFR-AK-CAZ-SC(3) NOT an Actual Survey 10 3/4"x 13-1/2 2,988.78 67.24 53.33 2,536.68 2,430.15 367.11 1,063.48 5,959,729.48 561,731.26 1.06 456.81 MWD+IFR-AK-CAZ-SC(3) 3,040.58 67.93 53.62 2,556.43 2,449.90 395.61 1,101.96 5,959,758.29 561,769.51 1.43 462.21 MWD+IFR-AK-CAZ-SC(3) 3,135.94 70.91 52.93 2,589.95 2,483.42 448.99 1,173.51 5,959,812.24 561,840.61 3.20 471.96 MWD+IFR-AK-CAZ-SC(3) 3,230.50 73.39 52.28 2,618.93 2,512.40 503.65 1,245.01 5,959,867.47 561,911.66 2.70 480.74 MWD+IFR-AK-CAZ-SC(3) 3,325.04 72.98 50.58 2,646.28 2,539.75 560.07 1,315.76 5,959,924.45 561,981.95 1.78 487.74 MWD+IFR-AK-CAZ-SC(3) 3,420.29 72.72 49.32 2,674.37 2,567.84 618.63 1,385.43 5,959,983.57 562,051.14 1.29 492.42 MWD+IFR-AK-CAZ-SC(3) 3,515.37 72.63 49.10 2,702.68 2,596.15 677.93 1,454.15 5,960,043.41 562,119.37 0.24 495.92 MWD+IFR-AK-CAZ-SC(3) 3,609.44 72.39 48.78 2,730.95 2,624.42 736.86 1,521.80 5,960,102.88 562,186.54 0.41 498.96 MWD+IFR-AK-CAZ-SC(3) 3,704.43 72.20 50.15 2,759.84 2,653.31 795.67 1,590.57 5,960,162.24 562,254.82 1.39 502.85 MWD+IFR-AK-CAZ-SC(3) 3,799.20 70.53 50.75 2,790.12 2,683.59 852.85 1,659.81 5,960,219.97 562,323.59 1.86 508.25 MWD+IFR-AK-CAZ-SC(3) 3,894.52 69.62 53.19 2,822.61 2,716.08 908.06 1,730.39 5,960,275.74 562,393.72 2.59 516.01 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 10:09:41AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1 D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 3,988.94 69.71 52.76 2,855.42 2,748.89 961.37 1,801.07 5,960,329.62 562,463.96 0.44 525.22 MWD+IFR-AK-CAZ-SC(3) 4,084.38 68.50 52.52 2,889.46 2,782.93 1,015.48 1,871.94 5,960,384.29 562,534.38 1.29 533.99 MWD+IFR-AK-CAZ-SC(3) 4,179.59 68.27 51.95 2,924.54 2,818.01 1,069.69 1,941.92 5,960,439.06 562,603.91 0.61 542.06 MWD+IFR-AK-CAZ-SC(3) 4,274.27 68.83 49.82 2,959.16 2,852.63 1,125.28 2,010.28 5,960,495.19 562,671.82 2.18 548.03 MWD+IFR-AK-CAZ-SC(3) 4,368.76 68.88 50.19 2,993.25 2,886.72 1,181.92 2,077.80 5,960,552.37 562,738.87 0.37 552.65 MWD+IFR-AK-CAZ-SC(3) 4,463.80 68.68 52.46 3,027.65 2,921.12 1,237.28 2,146.96 5,960,608.28 562,807.57 2.24 559.33 MWD+I FR-AK-CAZ-SC(3) 4,558.15 68.93 55.18 3,061.77 2,955.24 1,289.20 2,217.95 5,960,660.77 562,878.14 2.70 569.78 MWD+IFR-AK-CAZ-SC(3) 4,653.14 69.31 56.91 3,095.63 2,989.10 1,338.77 2,291.57 5,960,710.93 562,951.35 1.75 583.73 MWD+IFR-AK-CAZ-SC(3) 4,748.17 69.17 59.14 3,129.31 3,022.78 1,385.82 2,366.94 5,960,758.58 563,026.33 2.20 600.72 MWD+IFR-AK-CAZ-SC(3) 4,842.93 69.24 60.42 3,162.96 3,056.43 1,430.41 2,443.49 5,960,803.78 563,102.50 1.26 620.32 MWD+IFR-AK-CAZ-SC(3) 4,937.69 69.20 62.09 3,196.58 3,090.05 1,473.01 2,521.16 5,960,847.01 563,179.82 1.65 642.13 MWD+IFR-AK-CAZ-SC(3) 5,032.74 69.50 63.72 3,230.10 3,123.57 1,513.52 2,600.34 5,960,888.15 563,258.67 1.64 666.51 MWD+IFR-AK-CAZ-SC(3) 5,127.24 68.95 64.83 3,263.62 3,157.09 1,551.87 2,679.94 5,960,927.14 563,337.94 1.24 692.74 MWD+IFR-AK-CAZ-SC(3) 5,222.04 69.19 66.13 3,297.49 3,190.96 1,588.62 2,760.49 5,960,964.53 563,418.19 1.31 720.81 MWD+I FR-AK-CAZ-SC(3) 5,317.25 69.21 67.12 3,331.30 3,224.77 1,623.93 2,842.19 5,961,000.50 563,499.60 0.97 750.70 MWD+IFR-AK-CAZ-SC(3) 5,411.11 69.28 67.71 3,364.56 3,258.03 1,657.64 2,923.23 5,961,034.86 563,580.35 0.59 781.32 MWD+IFR-AK-CAZ-SC(3) 5,505.57 69.53 69.06 3,397.79 3,291.26 1,690.21 3,005.43 5,961,068.09 563,662.28 1.36 813.56 MWD+IFR-AK-CAZ-SC(3) 5,599.93 69.14 70.94 3,431.09 3,324.56 1,720.41 3,088.39 5,961,098.95 563,744.99 1.91 848.05 MWD+IFR-AK-CAZ-SC(3) 5,694.11 69.17 73.53 3,464.61 3,358.08 1,747.26 3,172.20 5,961,126.47 563,828.57 2.57 885.57 MWD+IFR-AK-CAZ-SC(3) 5,789.14 69.60 75.49 3,498.07 3,391.54 1,771.01 3,257.91 5,961,150.91 563,914.07 1.98 926.66 MWD+IFR-AK-CAZ-SC(3) 5,884.45 70.26 79.01 3,530.79 3,424.26 1,790.76 3,345.21 5,961,171.36 564,001.20 3.54 971.75 MWD+IFR-AK-CAZ-SC(3) 5,979.24 70.60 79.97 3,562.54 3,456.01 1,807.05 3,433.02 5,961,188.36 564,088.87 1.02 1,019.73 MWD+IFR-AK-CAZ-SC(3) 6,073.97 71.45 82.89 3,593.34 3,486.81 1,820.39 3,521.59 5,961,202.42 564,177.33 3.05 1,070.37 MWD+IFR-AK-CAZ-SC(3) 6,169.63 71.67 85.65 3,623.61 3,517.08 1,829.45 3,611.88 5,961,212.20 564,267.53 2.75 1,125.32 MWD+IFR-AK-CAZ-SC(3) 6,264.37 71.69 87.30 3,653.39 3,546.86 1,834.98 3,701.64 5,961,218.45 564,357.23 1.65 1,182.50 MWD+IFR-AK-CAZ-SC(3) 6,358.54 73.75 88.48 3,681.36 3,574.83 1,838.28 3,791.50 5,961,222.48 564,447.05 2.49 1,241.36 MWD+IFR-AK-CAZ-SC(3) 6,452.61 76.13 89.92 3,705.80 3,599.27 1,839.54 3,882.32 5,961,224.48 564,537.85 2.93 1,302.38 MWD+IFR-AK-CAZ-SC(3) 6,548.32 78.32 91.35 3,726.97 3,620.44 1,838.50 3,975.64 5,961,224.19 564,631.17 2.71 1,366.79 MWD+IFR-AK-CAZ-SC(3) 6,644.01 80.75 92.73 3,744.35 3,637.82 1,835.15 4,069.67 5,961,221.60 564,725.21 2.91 1,433.37 MWD+IFR-AK-CAZ-SC(3) 6,738.77 82.33 94.65 3,758.29 3,651.76 1,829.11 4,163.20 5,961,216.32 564,818.78 2.61 1,501.56 MWD+IFR-AK-CAZ-SC(3) 6,833.32 83.18 99.01 3,770.22 3,663.69 1,817.96 4,256.30 5,961,205.92 564,911.96 4.66 1,573.22 MWD+IFR-AK-CAZ-SC(3) 6,928.37 84.24 102.96 3,780.64 3,674.11 1,799.96 4,349.03 5,961,188.67 565,004.82 4.28 1,649.63 MWD+IFR-AK-CAZ-SC(3) 6,973.47 84.57 106.20 3,785.03 3,678.50 1,788.66 4,392.46 5,961,177.72 565,048.34 7.19 1,687.51 MWD+I F R-AK-CAZ-SC(3) 7,022.57 84.84 108.64 3,789.57 3,683.04 1,774.02 4,439.11 5,961,163.46 565,095.10 4.98 1,730.03 MWD+IFR-AK-CAZ-SC(3) 7,117.86 85.35 113.20 3,797.72 3,691.19 1,740.13 4,527.77 5,961,130.29 565,184.02 4.80 1,815.28 MWD+IFR-AK-CAZ-SC(3) 7,212.95 86.30 117.24 3,804.64 3,698.11 1,699.73 4,613.54 5,961,090.59 565,270.11 4.35 1,903.33 MWD+IFR-AK-CAZ-SC(3) 7,307.97 85.96 121.49 3,811.06 3,704.53 1,653.25 4,696.15 5,961,044.78 565,353.08 4.48 1,993.65 MWD+IFR-AK-CAZ-SC(3) 7,403.49 85.39 126.26 3,818.27 3,711.74 1,600.18 4,775.20 5,960,992.35 565,432.55 5.02 2,086.38 MWD+IFR-AK-CAZ-SC(3) 7,497.74 84.54 130.57 3,826.54 3,720.01 1,541.86 4,848.75 5,960,934.64 565,506.56 4.64 2,179.20 MWD+IFR-AK-CAZ-SC(3) 7,592.16 84.26 134.05 3,835.76 3,729.23 1,478.61 4,918.23 5,960,871.96 565,576.54 3.68 2,272.84 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 10:09:41AM Page 4 COMPASS 5000.1 Build 74 1111/ Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1 D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146 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) (°1100') (ft) Survey Tool Name 7,687.77 84.58 136.64 3,845.06 3,738.53 1,410.93 4,985.11 5,960,804.82 565,643.95 2.72 2,367.94 MWD+IFR-AK-CAZ-SC(3) 7,731.41 84.85 137.26 3,849.08 3,742.55 1,379.18 5,014.77 5,960,773.31 565,673.87 1.54 2,411.40 MWD+IFR-AK-CAZ-SC(3) 7,796.50 86.07 137.30 3,854.23 3,747.70 1,331.51 5,058.79 5,960,726.00 565,718.27 1.88 2,476.28 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 7-5/8"x 9-7/8" 7,823.00 86.57 137.32 3,855.93 3,749.40 1,312.07 5,076.72 5,960,706.71 565,736.35 1.88 2,502.73 MWD+IFR-AK-CAZ-SC(4) 7,890.37 88.84 140.53 3,858.63 3,752.10 1,261.33 5,120.94 5,960,656.34 565,780.98 5.83 2,569.99 MWD+IFR-AK-CAZ-SC(4) 7,985.15 90.07 140.70 3,859.53 3,753.00 1,188.08 5,181.07 5,960,583.58 565,841.70 1.31 2,664.58 MWD+IFR-AK-CAZ-SC(4) 8,079.71 92.17 144.81 3,857.68 3,751.15 1,112.84 5,238.28 5,960,508.82 565,899.50 4.88 2,758.62 MWD+IFR-AK-CAZ-SC(4) 8,174.57 90.66 146.36 3,855.34 3,748.81 1,034.61 5,291.87 5,960,431.03 565,953.72 2.28 2,852.38 MWD+IFR-AK-CAZ-SC(4) 8,268.99 89.66 148.55 3,855.07 3,748.54 955.02 5,342.66 5,960,351.86 566,005.15 2.55 2,945.23 MWD+IFR-AK-CAZ-SC(4) 8,364.29 89.73 150.99 3,855.58 3,749.05 872.69 5,390.64 5,960,269.93 566,053.78 2.56 3,038.16 MWD+IFR-AK-CAZ-SC(4) 8,459.42 89.28 152.33 3,856.40 3,749.87 788.97 5,435.79 5,960,186.58 566,099.61 1.49 3,130.19 MWD+IFR-AK-CAZ-SC(4) 8,553.21 89.59 153.95 3,857.33 3,750.80 705.30 5,478.17 5,960,103.27 566,142.65 1.76 3,220.27 MWD+IFR-AK-CAZ-SC(4) 8,648.67 89.87 151.95 3,857.78 3,751.25 620.29 5,521.58 5,960,018.62 566,186.74 2.12 3,312.05 MWD+IFR-AK-CAZ-SC(4) 8,743.70 89.66 149.67 3,858.17 3,751.64 537.34 5,567.92 5,959,936.05 566,233.75 2.41 3,404.33 MWD+IFR-AK-CAZ-SC(4) 8,838.00 88.91 147.61 3,859.34 3,752.81 456.82 5,616.99 5,959,855.94 566,283.46 2.32 3,496.68 MWD+IFR-AK-CAZ-SC(4) 8,932.53 89.28 146.60 3,860.84 3,754.31 377.46 5,668.32 5,959,777.00 566,335.42 1.14 3,589.73 MWD+IFR-AK-CAZ-SC(4) 9,027.23 89.35 146.53 3,861.97 3,755.44 298.44 5,720.49 5,959,698.41 566,388.23 0.10 3,683.10 MWD+IFR-AK-CAZ-SC(4) 9,122.96 89.90 150.25 3,862.60 3,756.07 216.93 5,770.66 5,959,617.32 566,439.05 3.93 3,776.93 MWD+IFR-AK-CAZ-SC(4) 9,217.80 89.25 152.16 3,863.30 3,756.77 133.82 5,816.34 5,959,534.59 566,485.39 2.13 3,868.86 MWD+IFR-AK-CAZ-SC(4) 9,312.74 89.94 155.90 3,863.97 3,757.44 48.49 5,857.90 5,959,449.60 566,527.64 4.01 3,959.62 MWD+IFR-AK-CAZ-SC(4) 9,407.81 89.70 155.40 3,864.27 3,757.74 -38.13 5,897.10 5,959,363.32 566,567.53 0.58 4,049.70 MWD+IFR-AK-CAZ-SC(4) 9,502.13 90.28 154.15 3,864.29 3,757.76 -123.45 5,937.30 5,959,278.33 566,608.41 1.46 4,139.51 MWD+IFR-AK-CAZ-SC(4) 9,597.40 90.69 153.94 3,863.48 3,756.95 -209.11 5,978.99 5,959,193.02 566,650.79 0.48 4,230.59 MWD+IFR-AK-CAZ-SC(4) 9,691.74 90.69 153.15 3,862.34 3,755.81 -293.56 6,021.02 5,959,108.91 566,693.49 0.84 4,321.02 MWD+IFR-AK-CAZ-SC(4) 9,786.19 90.18 152.31 3,861.63 3,755.10 -377.51 6,064.29 5,959,025.32 566,737.44 1.04 4,411.93 MWD+IFR-AK-CAZ-SC(4) 9,880.93 89.49 150.80 3,861.90 3,755.37 -460.81 6,109.41 5,958,942.40 566,783.23 1.75 4,503.63 MWD+IFR-AK-CAZ-SC(4) 9,976.50 89.32 154.81 3,862.89 3,756.36 -545.79 6,153.08 5,958,857.78 566,827.58 4.20 4,595.56 MWD+IFR-AK-CAZ-SC(4) 10,070.99 90.31 158.81 3,863.20 3,756.67 -632.63 6,190.28 5,958,771.26 566,865.47 4.36 4,684.44 MWD+IFR-AK-CAZ-SC(4) 10,166.30 90.31 161.27 3,862.68 3,756.15 -722.21 6,222.81 5,958,681.95 566,898.72 2.58 4,772.14 MWD+IFR-AK-CAZ-SC(4) 10,261.14 90.18 164.77 3,862.28 3,755.75 -812.90 6,250.51 5,958,591.50 566,927.15 3.69 4,857.35 MWD+IFR-AK-CAZ-SC(4) 10,355.88 90.79 167.80 3,861.47 3,754.94 -904.92 6,272.96 5,958,499.67 566,950.34 3.26 4,939.97 MWD+IFR-AK-CAZ-SC(4) 10,451.55 91.38 170.66 3,859.66 3,753.13 -998.88 6,290.84 5,958,405.87 566,968.97 3.05 5,020.87 MWD+IFR-AK-CAZ-SC(4) 10,546.42 90.62 172.59 3,858.01 3,751.48 -1,092.72 6,304.65 5,958,312.15 566,983.54 2.19 5,098.93 MWD+IFR-AK-CAZ-SC(4) 10,641.28 90.62 174.97 3,856.98 3,750.45 -1,187.01 6,314.93 5,958,217.96 566,994.58 2.51 5,174.89 MWD+IFR-AK-CAZ-SC(4) 10,735.27 90.66 176.84 3,855.93 3,749.40 -1,280.75 6,321.64 5,958,124.28 567,002.05 1.99 5,248.03 MWD+IFR-AK-CAZ-SC(4) 10,829.85 90.72 177.70 3,854.79 3,748.26 -1,375.21 6,326.14 5,958,029.87 567,007.31 0.91 5,320.19 MWD+IFR-AK-CAZ-SC(4) 10,925.21 90.76 177.66 3,853.56 3,747.03 -1,470.49 6,330.00 5,957,934.64 567,011.94 0.06 5,392.50 MWD+IFR-AK-CAZ-SC(4) 11,020.27 90.69 177.04 3,852.36 3,745.83 -1,565.44 6,334.40 5,957,839.73 567,017.10 0.66 5,464.94 MWD+IFR-AK-CAZ-SC(4) 11,115.07 90.00 176.00 3,851.78 3,745.25 -1,660.06 6,340.15 5,957,745.17 567,023.62 1.32 5,538.06 MWD+IFR-AK-CAZ-SC(4) 11,210.11 90.24 175.62 3,851.59 3,745.06 -1,754.84 6,347.10 5,957,650.45 567,031.33 0.47 5,612.12 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 10:09:41AM Page 5 COMPASS 5000.1 Build 74 411 Schlumberger . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) l' Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 q1 11,304.64 90.52 175.19 3,850.96 3,744.43 -1,849.07 6,354.67 5,957,556.30 567,039.66 0.54 5,686.20 MWD+IFR-AK-CAZ-SC(4) 11,400.44 90.59 176.77 3,850.03 3,743.50 -1,944.62 6,361.38 5,957,460.81 567,047.15 1.65 5,760.66 MWD+IFR-AK-CAZ-SC(4) 11,495.11 90.11 179.28 3,849.45 3,742.92 -2,039.23 6,364.65 5,957,366.25 567,051.17 2.70 5,832.08 MWD+IFR-AK-CAZ-SC(4) 11,589.77 90.48 178.35 3,848.96 3,742.43 -2,133.87 6,366.60 5,957,271.64 567,053.89 1.06 5,902.62 MWD+IFR-AK-CAZ-SC(4) 11,684.85 91.00 177.56 3,847.74 3,741.21 -2,228.88 6,370.00 5,957,176.67 567,058.05 0.99 5,974.42 MWD+IFR-AK-CAZ-SC(4) 11,779.54 91.55 178.45 3,845.63 3,739.10 -2,323.48 6,373.29 5,957,082.10 567,062.11 1.10 6,045.86 MWD+IFR-AK-CAZ-SC(4) 11,874.64 90.31 179.95 3,844.09 3,737.56 -2,418.56 6,374.62 5,956,987.05 567,064.21 2.05 6,116.30 MWD+I FR-AK-CAZ-SC(4) 11,969.01 89.94 182.20 3,843.88 3,737.35 -2,512.91 6,372.85 5,956,892.70 567,063.20 2.42 6,184.10 MWD+IFR-AK-CAZ-SC(4) 12,064.45 89.76 184.11 3,844.13 3,737.60 -2,608.20 6,367.60 5,956,797.38 567,058.72 2.01 6,250.20 MWD+IFR-AK-CAZ-SC(4) 12,159.07 91.07 183.49 3,843.44 3,736.91 -2,702.60 6,361.33 5,956,702.93 567,053.21 1.53 6,314.97 MWD+IFR-AK-CAZ-SC(4) 12,253.55 91.00 182.12 3,841.74 3,735.21 -2,796.95 6,356.70 5,956,608.56 567,049.35 1.45 6,380.82 MWD+IFR-AK-CAZ-SC(4) 12,349.01 91.51 181.66 3,839.65 3,733.12 -2,892.34 6,353.56 5,956,513.16 567,046.97 0.72 6,448.44 MWD+IFR-AK-CAZ-SC(4) 12,442.86 91.86 180.20 3,836.89 3,730.36 -2,986.13 6,352.03 5,956,419.36 567,046.21 1.60 6,515.99 MWD+IFR-AK-CAZ-SC(4) 12,538.02 91.79 178.87 3,833.86 3,727.33 -3,081.24 6,352.81 5,956,324.28 567,047.75 1.40 6,586.08 MWD+IFR-AK-CAZ-SC(4) 12,632.87 91.14 177.00 3,831.43 3,724.90 -3,175.99 6,356.22 5,956,229.56 567,051.93 2.09 6,657.71 MWD+IFR-AK-CAZ-SC(4) 12,728.19 90.38 177.71 3,830.17 3,723.64 -3,271.20 6,360.62 5,956,134.40 567,057.09 1.09 6,730.34 MWD+IFR-AK-CAZ-SC(4) 12,822.93 90.69 177.87 3,829.28 3,722.75 -3,365.86 6,364.27 5,956,039.78 567,061.51 0.37 6,802.06 MWD+IFR-AK-CAZ-SC(4) 12,917.38 90.66 178.16 3,828.17 3,721.64 -3,460.25 6,367.55 5,955,945.43 567,065.54 0.31 6,873.32 MWD+IFR-AK-CAZ-SC(4) 13,013.63 90.69 178.55 3,827.04 3,720.51 -3,556.45 6,370.31 5,955,849.26 567,069.08 0.41 6,945.57 MWD+IFR-AK-CAZ-SC(4) 13,104.67 91.31 177.91 3,825.45 3,718.92 -3,647.44 6,373.12 5,955,758.31 567,072.63 0.98 7,014.02 MWD+IFR-AK-CAZ-SC(4) 13,199.74 92.23 178.21 3,822.51 3,715.98 -3,742.41 6,376.34 5,955,663.38 567,076.61 1.02 7,085.67 MWD+IFR-AK-CAZ-SC(4) 13,295.24 90.14 176.91 3,820.54 3,714.01 -3,837.79 6,380.40 5,955,568.04 567,081.45 2.58 7,158.21 MWD+IFR-AK-CAZ-SC(4) 13,390.34 90.28 174.30 3,820.19 3,713.66 -3,932.60 6,387.69 5,955,473.30 567,089.50 2.75 7,232.52 MWD+IFR-AK-CAZ-SC(4) 13,487.95 90.62 172.89 3,819.42 3,712.89 -4,029.60 6,398.58 5,955,376.41 567,101.17 1.49 7,310.88 MWD+IFR-AK-CAZ-SC(4) 13,583.64 90.86 170.87 3,818.18 3,711.65 -4,124.32 6,412.09 5,955,281.81 567,115.44 2.13 7,389.37 MWD+IFR-AK-CAZ-SC(4) 13,678.08 91.41 172.64 3,816.31 3,709.78 -4,217.76 6,425.63 5,955,188.49 567,129.74 1.96 7,466.94 MWD+IFR-AK-CAZ-SC(4) 13,773.15 90.72 175.42 3,814.55 3,708.02 -4,312.28 6,435.52 5,955,094.05 567,140.38 3.01 7,542.82 MWD+IFR-AK-CAZ-SC(4) 13,868.28 90.00 178.90 3,813.95 3,707.42 -4,407.28 6,440.23 5,954,999.11 567,145.86 3.74 7,615.51 MWD+IFR-AK-CAZ-SC(4) 13,963.30 90.76 179.57 3,813.32 3,706.79 -4,502.29 6,441.50 5,954,904.12 567,147.90 1.07 7,685.86 MWD+IFR-AK-CAZ-SC(4) 14,057.55 90.76 181.71 3,812.07 3,705.54 -4,596.52 6,440.44 5,954,809.90 567,147.61 2.27 7,754.05 MWD+IFR-AK-CAZ-SC(4) 14,152.85 90.90 184.12 3,810.69 3,704.16 -4,691.68 6,435.60 5,954,714.71 567,143.53 2.53 7,820.34 MWD+IFR-AK-CAZ-SC(4) 14,246.38 90.07 187.22 3,809.90 3,703.37 -4,784.74 6,426.36 5,954,621.59 567,135.04 3.43 7,882.10 MWD+IFR-AK-CAZ-SC(4) 14,341.56 90.69 189.05 3,809.26 3,702.73 -4,878.95 6,412.89 5,954,527.28 567,122.34 2.03 7,941.82 MWD+IFR-AK-CAZ-SC(4) 14,436.03 91.03 188.61 3,807.85 3,701.32 -4,972.29 6,398.39 5,954,433.83 567,108.59 0.59 8,000.20 MWD+IFR-AK-CAZ-SC(4) 14,532.50 91.75 187.79 3,805.51 3,698.98 -5,067.75 6,384.64 5,954,338.28 567,095.61 1.13 8,060.63 MWD+IFR-AK-CAZ-SC(4) 14,626.56 91.07 187.25 3,803.19 3,696.66 -5,160.97 6,372.33 5,954,244.97 567,084.06 0.92 8,120.41 MWD+IFR-AK-CAZ-SC(4) 14,719.82 90.62 184.71 3,801.82 3,695.29 -5,253.70 6,362.62 5,954,152.17 567,075.09 2.77 8,181.61 MWD+IFR-AK-CAZ-SC(4) 14,816.50 91.27 181.97 3,800.22 3,693.69 -5,350.19 6,356.99 5,954,055.64 567,070.24 2.91 8,248.34 MWD+IFR-AK-CAZ-SC(4) 14,908.36 91.27 180.70 3,798.19 3,691.66 -5,442.01 6,354.85 5,953,963.83 567,068.84 1.38 8,314.03 MWD+IFR-AK-CAZ-SC(4) 15,001.29 90.72 177.50 3,796.57 3,690.04 -5,534.90 6,356.31 5,953,870.96 567,071.05 3.49 8,382.96 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 10:09:41AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1 D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,095.57 91.07 174.74 3,795.10 3,688.57 -5,628.94 6,362.68 5,953,776.98 567,078.19 2.95 8,456.09 MWD+IFR-AK-CAZ-SC(4) 15,185.08 90.45 174.94 3,793.91 3,687.38 -5,718.08 6,370.73 5,953,687.92 567,086.96 0.73 8,526.77 MWD+IFR-AK-CAZ-SC(4) 15,233.18 90.62 176.67 3,793.46 3,686.93 -5,766.05 6,374.25 5,953,639.98 567,090.86 3.61 8,564.25 MWD+IFR-AK-CAZ-SC(4) 15,278.40 90.59 177.87 3,792.98 3,686.45 -5,811.21 6,376.40 5,953,594.84 567,093.38 2.65 8,598.75 MWD+IFR-AK-CAZ-SC(4) 15,322.73 90.83 178.70 3,792.43 3,685.90 -5,855.52 6,377.73 5,953,550.55 567,095.07 1.95 8,632.06 MWD+IFR-AK-CAZ-SC(4) 15,371.45 90.79 180.27 3,791.75 3,685.22 -5,904.23 6,378.17 5,953,501.85 567,095.90 3.22 8,667.98 MWD+IFR-AK-CAZ-SC(4) 15,464.30 90.31 179.48 3,790.85 3,684.32 -5,997.07 6,378.37 5,953,409.02 567,096.85 1.00 8,736.02 MWD+IFR-AK-CAZ-SC(4) 15,556.99 90.11 178.39 3,790.51 3,683.98 -6,089.75 6,380.09 5,953,316.37 567,099.32 1.20 8,804.97 MWD+IFR-AK-CAZ-SC(4) 15,649.47 90.83 177.74 3,789.76 3,683.23 -6,182.17 6,383.22 5,953,223.99 567,103.19 1.05 8,874.70 MWD+IFR-AK-CAZ-SC(4) 15,740.60 91.14 177.16 3,788.19 3,681.66 -6,273.20 6,387.27 5,953,133.01 567,107.98 0.72 8,944.03 MWD+IFR-AK-CAZ-SC(4) 15,832.70 90.24 178.00 3,787.08 3,680.55 -6,365.20 6,391.16 5,953,041.04 567,112.61 1.34 9,013.98 MWD+IFR-AK-CAZ-SC(4) 15,923.64 89.22 177.84 3,787.51 3,680.98 -6,456.08 6,394.46 5,952,950.20 567,116.64 1.14 9,082.69 MWD+IFR-AK-CAZ-SC(4) 16,015.37 88.43 176.14 3,789.39 3,682.86 -6,547.66 6,399.28 5,952,858.67 567,122.19 2.04 9,152.95 MWD+IFR-AK-CAZ-SC(4) 16,108.82 88.67 175.65 3,791.76 3,685.23 -6,640.84 6,405.96 5,952,765.56 567,129.63 0.58 9,225.66 MWD+IFR-AK-CAZ-SC(4) 16,200.40 88.43 175.66 3,794.07 3,687.54 -6,732.13 6,412.90 5,952,674.34 567,137.31 0.26 9,297.15 MWD+IFR-AK-CAZ-SC(4) 16,292.91 90.62 178.19 3,794.84 3,688.31 -6,824.49 6,417.86 5,952,582.03 567,143.01 3.62 9,368.09 MWD+IFR-AK-CAZ-SC(4) 16,385.49 90.62 179.07 3,793.84 3,687.31 -6,917.04 6,420.07 5,952,489.51 567,145.97 0.95 9,437.28 MWD+IFR-AK-CAZ-SC(4) 16,412.21 90.66 178.12 3,793.54 3,687.01 -6,943.75 6,420.73 5,952,462.81 567,146.84 3.56 9,457.26 MWD+IFR-AK-CAZ-SC(4) 16,462.00 90.66 178.12 3,792.97 3,686.44 -6,993.51 6,422.36 5,952,413.07 567,148.88 0.00 9,494.77 NOT an Actual Survey 4 1/2"x 6-3/4" 16,472.00 90.66 178.12 3,792.85 3,686.32 -7,003.50 6,422.69 5,952,403.08 567,149.29 0.00 9,502.30 PROJECTED to TD Final Definitive Survey Verified and Signed-off Ali targets and/or well position objectives have been achieved. yes LJ No I have checked to the best of my ability that the following data is correct: El Surface Coordinates Q Declination & Convergence ( GRS Survey Corrections 2 Survey Tool Codes DigDN:ndiym-Wigand Ctsara;igned by'Oman!lardVincent 0sara u SLB DE: fenzawasaraesfb urn,c-US Dut¢M85A7.151 R23124-34116 p Cog .l /�,Y tolt ':iyM Ire ratoHOW# Kelsey I 1 5✓1 -xhunx. opxamo i$ rc PAM, Client Representative: Ilt,n b 2161 1M1 1td5 Date_ 15-Jul-2015 7/15/2015 10:09.41AM Page 7 COMPASS 5000.1 Build 74 • • Cement Detail Report oz 1D-146 Corso 'Iii String: Conductor Cement Job: DRILLING ORIGINAL, 6/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 11/24/2014 11:16 11/24/2014 11:20 1D-146 Comment Tacked bottom of conductor with first stage,then cemented to within 5'of surface for the cellar box, later the same day. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement conductor 56.2 116.0 Yes No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) AS1 56.2 116.0 58 9.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 0.93 15.70 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement conductor 45.0 56.2 Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) AS1 45.0 56.2 120 19.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 0.93 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 8/13/2015 • i ` i l j Cement Detail Report F frp �� 1D-146 conocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/25/2015 16:00 6/25/2015 20:15 1D-146 Comment PJSM for cement job with SLB cementers,truck drivers, rig crew and CPAI rep. Circulate @ 7 bpm and recip 20'from 2961'to 2941'. Dowell pump 5 bbls water, then test to 3500 psi-good. Batch up MudPushll at 10.5 ppg with 2-1/2 gallons of red dye. Pump 45 bbls of CW-100 at 5.5 bpm. Pump 100 bbls of 10.5 ppg MudPush II with red dye,avg 5.5 bpm. Recip casing 20'. PUW 178k, SOW 124k. Load bottom plug, install with the Volant casing tool. Batch 11 ppg cement with 90°water. Pump cement at avg of 6.6 bpm at 240-260 psi. Pump 415 bbls(1234 sx) empty SLB tub for a total of 429 bbls LiteCrete cement. Recip casing 20'. PU wt 166k, SO wt 109k. Batch up LiteCrete tail cement to 12 ppg, Dowell pump LiteCrete tail cement at average of 4 bpm at150-200 psi.Sticky, landed casing on hanger at 18:46 hrs. Pumped a total of 58 bbls(194 sx). Load top plug, install with the Volant casing tool. Dowell pump 10 bbls of water to clear lines at 6 bpm,217 psi. Rig displaced cement with 9.6 ppg Drilplex mud.displace with rig pump at 8 bpm at 547 psi taking returns to the shakers, By-pass shakers to cuttings tank when red dye was seen.Slow down to 3 bpm at 407 psi after pumping 260 bbls, bumped the plug at 264 bbls, pumped(95%pump efficiency, 2637 strokes).69 bbls cement back to the pits.Floats did not hold.Hold 120 psi f/13 hrs,500 psi compressive strength. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,991.0 No 69.0 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) 5 3 5 121.0 420.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM for cement job with SLB cementers,truck drivers, rig crew and CPAI rep. Circ @ 7 bpm&recip 20'f/2961'to 2941'. Dowell pump 5 bbls water,then test to 3500 psi-good. Batch up MudPushll @ 10.5 ppg w/2-1/2 gallons of red dye. Pump 45 bbls of CW-100 at 5.5 bpm. Pump 100 bbls of 10.5 ppg MudPush II w/2- 1/2 gallons of red dye,avg 5.5 bpm. Recip casing 20'. PU wt 178k,SO wt 124k. Load bottom plug, install with the Volant casing tool. Batch 11 ppg cement with 90°water. Pump cement @ avg of 5.5 bpm w/240-260 psi. Pumped a total of 415 bbls(1234 sx)when Finished pump down tanks for a total of 429 bbls ACL cement. Recip casing 20'. PU wt 166k,SO wt 109k. Batch up LiteCrete tail cement to 12 ppg, Dowell pump LiteCrete tail cement @ average of 4 bpm w/150- 200 psi.Sticky, landed casing on hanger at 18:46 hrs. Pumped a total of 58 bbls(194 sx). Load top plug, install with the Volant casing tool. Dowell pump 10 bbls of water to clear lines @ 6 bpm at 217 psi. Rig displaced cement w/9.6 ppg Drilplex mud. Initially displacing @ 8 bpm w/547 psi taking returns to the shakers, By-pass shakers to cuttings tank when red dye was seen. Slow down to 3 bpm at 407 psi after pumping 260 bbls and bumped the plug at 264 bbls pumped (95%pump efficiency,2637 strokes). 69 bbls cement to surface. Floats did not hold. Hold 120 psi f/13 hrs, 500 psi compressive strength. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 100.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 0.0 2,971.0 1,234 G 429.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.74 11.00 67.5 0.00 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispers 0.07 gal/sx Additive Type Concentration Conc Unit label D177 Retarder 0.01 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,471.0 2,971.0 194 G 58.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.62 5.38 12.00 86.8 0.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Page 1/2 Report Printed: 8/13/2015 • • Cement Detail Report h M 1D-146 Philtips Ar.k:, String: Intermediate casing cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate casing cement 7/2/2015 15:30 7/2/2015 18:00 1D-146 Comment PJSM; PJSM with SLB, rig crew,Veto GE, GBR, and CPAI repsto discuss cement procedure. Continue to circulate and condition during meeting. SLB Pump 35.1 BBLs of CW100(40.1 BBL total)at 5.9 BPM with 470 psi,22%FO. Reciprocate string 18'off hanger. Batch and pump MudPush II 39.7 BBL of 11.5 ppg at 4.8 BPM with 320 psi, 19%FO. Break out Volant tool and drop Bottom plug at 16:11 hours. Engage Volant tool and batch 15.8 PPG cement. Pump 163.1 BBL(789 Sx at 1.16 yeild)cement at 5.7 BPM with ICP=420 psi, FCP=201 psi, 22%FO average. Drop Top plug at 16:51 hours. Pump 10 BBL water to clear lines and swap to Rig pumps. Chase Cement with 9.4 ppg mud at 6 BPM with ICP= 127 psi, FCP=695 psi.Slow to 4 BPM at 330 BBLs away, then slow to 3 BPM at 332 BBLs away. Bump plug with 3365 strokes;339 BBL, increase pressure to 1200 psi and hold until lined up to measure returns. Bled off pressure and floats;Good. CIP at 18:00 hours. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate casing Cement to>500'above 4,862.0 7,797.0 Yes Yes Yes cement UGNU B;4862'MD 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 6 6 695.0 700.0 Yes 18.00, No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 15.8 PPG, 1.16 yeild,789 Sacks, 163.1 BBL. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW-100 40.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.33 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 39.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.50 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 Slurry 4,863.0 7,797.0 791 G 163.1 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 4.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.005 gal/sx Page 1/1 Report Printed: 8/13/2015 0 • 0,':i ��i,R _ Cement Detail Report a��� IT c; 1D-146 CorxxoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL,6/19/2015 00:00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix FI20 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 8/13/2015 REOEIVED • 21 41 39 JUL 2421uj 26 070 S chiumberer OGCC Transmittal#: 24JUL15-SP01 g Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 1 r1/1/201E M K RENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-146 Date Dispatched: 24-Jul-15 Job#: 15AKA0092 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 5"MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso a(�,conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 .'' 6,,,,st Received By: • • 214139 26070 RECEIVED JUL 2 4 2015 FINAL AOGCC NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-146 Definitive Survey Report 15 July, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 1D-146 Well Position +N/-S 0.00 usft Northing: 5,959,353.83 usfi Latitude: 70°17'58.244 N +E/-W 0.00 usft Easting: 560,670.88 usfi Longitude: 149°30'31.111 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 67.10 usft Wellbore 1D-146 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 7/22/2015 18.84 80.92 57,556 Design 1D-146 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.43 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.43 0.00 0.00 137.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.00 466.00 1D-146 Srvy#1 GYD-GC-SS(1D-146) GYD-GC-SS Gyrodata gyro single shots 6/23/2015 8:2 495.29 2,898.04 1D-146 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 8:31 2,988.78 7,731.41 1D-146 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/24/2015 12:;: 7,823.00 16,412.21 1 D-146 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/6/2015 10:4: 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 39.43 0.00 0.00 39.43 -67.10 0.00 0.00 5,959,353.83 560,670.88 0.00 0.00 UNDEFINED 80.00 0.16 177.50 80.00 -26.53 -0.06 0.00 5,959,353.77 560,670.88 0.39 0.04 GYD-GC-SS(1) 121.00 0.14 188.79 121.00 14.47 -0.16 0.00 5,959,353.67 560,670.88 0.09 0.12 GYD-GC-SS(1) 158.00 0.24 182.95 158.00 51.47 -0.28 -0.01 5,959,353.55 560,670.87 0.27 0.20 GYD-GC-SS(11 NOT an Actual Survey 20"x 34" 216.00 0.39 179.66 216.00 109.47 -0.60 -0.02 5,959,353.23 560,670.87 0.27 0.43 GYD-GC-SS(1) 275.00 0.57 164.33 275.00 168.47 -1.08 0.06 5,959,352.75 560,670.95 0.37 0.84 GYD-GC-SS(1) 372.00 1.50 139.43 371.98 265.45 -2.51 1.02 5,959,351.32 560,671.92 1.04 2.53 GYD-GC-SS(1) 466.00 2.49 129.64 465.92 359.39 -4.75 3.39 5,959,349.11 560,674.31 1.11 5.79 GYD-GC-SS(1) 495.29 3.02 124.45 495.18 388.65 -5.59 4.52 5,959,348.27 560,675.44 2.00 7.17 MWD+IFR-AK-CAZ-SC(2) 588.03 4.24 115.21 587.73 481.20 -8.44 9.63 5,959,345.47 560,680.58 1.45 12.74 MWD+IFR-AK-CAZ-SC(2) 7/15/2015 10:09:41AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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) (°1100') (ft) Survey Tool Name 681.75 4.78 111.26 681.16 574.63 -11.33 16.41 5,959,342.64 560,687.38 0.66 19.47 MWD+IFR-AK-CAZ-SC(2) 776.91 5.10 105.70 775.97 669.44 -13.91 24.17 5,959,340.12 560,695.16 0.60 26.66 MWD+IFR-AK-CAZ-SC(2) 871.83 6.91 106.42 870.36 763.83 -16.67 33.71 5,959,337.44 560,704.72 1.91 35.18 MWD+IFR-AK-CAZ-SC(2) 970.63 10.80 104.09 967.97 861.44 -20.60 48.40 5,959,333.62 560,719.44 3.95 48.07 MWD+IFR-AK-CAZ-SC(2) 1,060.02 11.78 101.78 1,055.63 949.10 -24.50 65.45 5,959,329.86 560,736.52 1.21 62.56 MWD+IFR-AK-CAZ-SC(2) 1,112.51 11.50 102.87 1,107.04 1,000.51 -26.76 75.80 5,959,327.68 560,746.89 0.68 71.27 MWD+IFR-AK-CAZ-SC(2) 1,155.54 12.23 103.88 1,149.15 1,042.62 -28.81 84.41 5,959,325.70 560,755.51 1.76 78.64 MWD+IFR-AK-CAZ-SC(2) 1,250.98 14.85 104.07 1,241.93 1,135.40 -34.21 106.09 5,959,320.48 560,777.23 2.75 97.37 MWD+IFR-AK-CAZ-SC(2) 1,344.66 17.52 102.12 1,331.89 1,225.36 -40.09 131.52 5,959,314.81 560,802.71 2.91 119.02 MWD+IFR-AK-CAZ-SC(2) 1,439.69 20.51 97.07 1,421.73 1,315.20 -45.14 162.04 5,959,310.00 560,833.26 3.59 143.53 MWD+IFR-AK-CAZ-SC(2) 1,534.57 23.74 93.15 1,509.61 1,403.08 -48.24 197.61 5,959,307.19 560,868.86 3.74 170.05 MWD+IFR-AK-CAZ-SC(2) 1,628.39 27.45 88.85 1,594.22 1,487.69 -48.84 238.11 5,959,306.91 560,909.35 4.42 198.11 MWD+IFR-AK-CAZ-SC(2) 1,722.34 27.52 87.55 1,677.57 1,571.04 -47.48 281.44 5,959,308.63 560,952.67 0.64 226.67 MWD+IFR-AK-CAZ-SC(2) 1,817.50 31.97 81.11 1,760.19 1,653.66 -42.64 328.33 5,959,313.84 560,999.52 5.75 255.11 MWD+IFR-AK-CAZ-SC(2) 1,867.23 33.16 76.88 1,802.11 1,695.58 -37.52 354.59 5,959,319.18 561,025.73 5.16 269.27 MWD+IFR-AK-CAZ-SC(2) 1,912.16 33.17 75.32 1,839.72 1,733.19 -31.62 378.45 5,959,325.27 561,049.54 1.90 281.23 MWD+IFR-AK-CAZ-SC(2) 2,007.73 34.99 69.38 1,918.89 1,812.36 -15.34 429.41 5,959,341.96 561,100.35 3.97 304.07 MWD+IFR-AK-CAZ-SC(2) 2,101.57 37.97 64.91 1,994.35 1,887.82 6.39 480.75 5,959,364.10 561,151.52 4.25 323.20 MWD+IFR-AK-CAZ-SC(2) 2,197.38 39.13 62.81 2,069.28 1,962.75 32.70 534.34 5,959,390.84 561,204.89 1.83 340.50 MWD+IFR-AK-CAZ-SC(2) 2,291.79 42.43 60.59 2,140.77 2,034.24 61.96 588.60 5,959,420.54 561,258.90 3.82 356.11 MWD+IFR-AK-CAZ-SC(2) 2,387.77 44.47 59.71 2,210.44 2,103.91 94.82 645.84 5,959,453.86 561,315.87 2.22 371.11 MWD+IFR-AK-CAZ-SC(2) 2,481.16 48.90 58.56 2,274.49 2,167.96 129.70 704.14 5,959,489.19 561,373.88 4.83 385.37 MWD+IFR-AK-CAZ-SC(2) 2,574.34 51.86 58.30 2,333.91 2,227.38 167.27 765.28 5,959,527.26 561,434.71 3.18 399.59 MWD+IFR-AK-CAZ-SC(2) 2,668.73 53.77 58.19 2,390.95 2,284.42 206.85 829.22 5,959,567.34 561,498.33 2.03 414.25 MWD+IFR-AK-CAZ-SC(2) 2,764.04 59.97 56.48 2,443.02 2,336.49 249.94 896.35 5,959,610.97 561,565.10 6.68 428.52 MWD+IFR-AK-CAZ-SC(2) 2,809.43 64.01 56.25 2,464.33 2,357.80 272.13 929.71 5,959,633.43 561,598.28 8.91 435.04 MWD+IFR-AK-CAZ-SC(2) 2,858.60 65.87 55.91 2,485.16 2,378.63 296.99 966.67 5,959,658.58 561,635.03 3.83 442.07 MWD+IFR-AK-CAZ-SC(2) 2,898.04 66.55 54.06 2,501.07 2,394.54 317.69 996.22 5,959,679.53 561,664.41 4.63 447.08 MWD+IFR-AK-CAZ-SC(2) 2,961.00 67.03 53.55 2,525.88 2,419.35 351.86 1,042.92 5,959,714.07 561,710.83 1.06 453.93 MWD+IFR- K-CAZ-SC(31 10 3/4"x 13-1/2 NOT an Actual sir10 2,988.78 67.24 53.33 2,536.68 2,430.15 367.11 1,063.48 5,959,729.48 561,731.26 1.06 456.81 MWD+IFR-AK-CAZ-SC(3) 3,040.58 67.93 53.62 2,556.43 2,449.90 395.61 1,101.96 5,959,758.29 561,769.51 1.43 462.21 MWD+IFR-AK-CAZ-SC(3) 3,135.94 70.91 52.93 2,589.95 2,483.42 448.99 1,173.51 5,959,812.24 561,840.61 3.20 471.96 MWD+IFR-AK-CAZ-SC(3) 3,230.50 73.39 52.28 2,618.93 2,512.40 503.65 1,245.01 5,959,867.47 561,911.66 2.70 480.74 MWD+IFR-AK-CAZ-SC(3) 3,325.04 72.98 50.58 2,646.28 2,539.75 560.07 1,315.76 5,959,924.45 561,981.95 1.78 487.74 MWD+IFR-AK-CAZ-SC(3) 3,420.29 72.72 49.32 2,674.37 2,567.84 618.63 1,385.43 5,959,983.57 562,051.14 1.29 492.42 MWD+IFR-AK-CAZ-SC(3) 3,515.37 72.63 49.10 2,702.68 2,596.15 677.93 1,454.15 5,960,043.41 562,119.37 0.24 495.92 MWD+IFR-AK-CAZ-SC(3) 3,609.44 72.39 48.78 2,730.95 2,624.42 736.86 1,521.80 5,960,102.88 562,186.54 0.41 498.96 MWD+IFR-AK-CAZ-SC(3) 3,704.43 72.20 50.15 2,759.84 2,653.31 795.67 1,590.57 5,960,162.24 562,254.82 1.39 502.85 MWD+IFR-AK-CAZ-SC(3) 3,799.20 70.53 50.75 2,790.12 2,683.59 852.85 1,659.81 5,960,219.97 562,323.59 1.86 508.25 MWD+IFR-AK-CAZ-SC(3) 3,894.52 69.62 53.19 2,822.61 2,716.08 908.06 1,730.39 5,960,275.74 562,393.72 2.59 516.01 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 10:09:41AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 10-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,988.94 69.71 52.76 2,855.42 2,748.89 961.37 1,801.07 5,960,329.62 562,463.96 0.44 525.22 MW D+I FR-AK-CAZ-SC(3) 4,084.38 68.50 52.52 2,889.46 2,782.93 1,015.48 1,871.94 5,960,384.29 562,534.38 1.29 533.99 MWD+IFR-AK-CAZ-SC(3) 4,179.59 68.27 51.95 2,924.54 2,818.01 1,069.69 1,941.92 5,960,439.06 562,603.91 0.61 542.06 MW D+I FR-AK-CAZ-SC(3) 4,274.27 68.83 49.82 2,959.16 2,852.63 1,125.28 2,010.28 5,960,495.19 562,671.82 2.18 548.03 MWD+IFR-AK-CAZ-SC(3) 4,368.76 68.88 50.19 2,993.25 2,886.72 1,181.92 2,077.80 5,960,552.37 562,738.87 0.37 552.65 MW D+I FR-AK-CAZ-SC(3) 4,463.80 68.68 52.46 3,027.65 2,921.12 1,237.28 2,146.96 5,960,608.28 562,807.57 2.24 559.33 MW D+I FR-AK-CAZ-SC(3) 4,558.15 68.93 55.18 3,061.77 2,955.24 1,289.20 2,217.95 5,960,660.77 562,878.14 2.70 569.78 MW D+I FR-AK-CAZ-SC(3) 4,653.14 69.31 56.91 3,095.63 2,989.10 1,338.77 2,291.57 5,960,710.93 562,951.35 1.75 583.73 MWD+IFR-AK-CAZ-SC(3) 4,748.17 69.17 59.14 3,129.31 3,022.78 1,385.82 2,366.94 5,960,758.58 563,026.33 2.20 600.72 MWD+IFR-AK-CAZ-SC(3) 4,842.93 69.24 60.42 3,162.96 3,056.43 1,430.41 2,443.49 5,960,803.78 563,102.50 1.26 620.32 MWD+IFR-AK-CAZ-SC(3) 4,937.69 69.20 62.09 3,196.58 3,090.05 1,473.01 2,521.16 5,960,847.01 563,179.82 1.65 642.13 MWD+IFR-AK-CAZ-SC(3) 5,032.74 69.50 63.72 3,230.10 3,123.57 1,513.52 2,600.34 5,960,888.15 563,258.67 1.64 666.51 MWD+IFR-AK-CAZ-SC(3) 5,127.24 68.95 64.83 3,263.62 3,157.09 1,551.87 2,679.94 5,960,927.14 563,337.94 1.24 692.74 MWD+IFR-AK-CAZ-SC(3) 5,222.04 69.19 66.13 3,297.49 3,190.96 1,588.62 2,760.49 5,960,964.53 563,418.19 1.31 720.81 MW D+I FR-AK-CAZ-SC(3) 5,317.25 69.21 67.12 3,331.30 3,224.77 1,623.93 2,842.19 5,961,000.50 563,499.60 0.97 750.70 MW D+I FR-AK-CAZ-SC(3) 5,411.11 69.28 67.71 3,364.56 3,258.03 1,657.64 2,923.23 5,961,034.86 563,580.35 0.59 781.32 MW D+I FR-AK-CAZ-SC(3) 5,505.57 69.53 69.06 3,397.79 3,291.26 1,690.21 3,005.43 5,961,068.09 563,662.28 1.36 813.56 MW D+I FR-AK-CAZ-SC(3) 5,599.93 69.14 70.94 3,431.09 3,324.56 1,720.41 3,088.39 5,961,098.95 563,744.99 1.91 848.05 MW D+I FR-AK-CAZ-SC(3) 5,694.11 69.17 73.53 3,464.61 3,358.08 1,747.26 3,172.20 5,961,126.47 563,828.57 2.57 885.57 MW D+I FR-AK-CAZ-SC(3) 5,789.14 69.60 75.49 3,498.07 3,391.54 1,771.01 3,257.91 5,961,150.91 563,914.07 1.98 926.66 MWD+IFR-AK-CAZ-SC(3) 5,884.45 70.26 79.01 3,530.79 3,424.26 1,790.76 3,345.21 5,961,171.36 564,001.20 3.54 971.75 MW D+I FR-AK-CAZ-SC(3) 5,979.24 70.60 79.97 3,562.54 3,456.01 1,807.05 3,433.02 5,961,188.36 564,088.87 1.02 1,019.73 MWD+IFR-AK-CAZ-SC(3) 6,073.97 71.45 82.89 3,593.34 3,486.81 1,820.39 3,521.59 5,961,202.42 564,177.33 3.05 1,070.37 MWD+IFR-AK-CAZ-SC(3) 6,169.63 71.67 85.65 3,623.61 3,517.08 1,829.45 3,611.88 5,961,212.20 564,267.53 2.75 1,125.32 MWD+1FR-AK-CAZ-SC(3) 6,264.37 71.69 87.30 3,653.39 3,546.86 1,834.98 3,701.64 5,961,218.45 564,357.23 1.65 1,182.50 MW D+I FR-AK-CAZ-SC(3) 6,358.54 73.75 88.48 3,681.36 3,574.83 1,838.28 3,791.50 5,961,222.48 564,447.05 2.49 1,241.36 MW D+I FR-AK-CAZ-SC(3) 6,452.61 76.13 89.92 3,705.80 3,599.27 1,839.54 3,882.32 5,961,224.48 564,537.85 2.93 1,302.38 MWD+IFR-AK-CAZ-SC(3) 6,548.32 78.32 91.35 3,726.97 3,620.44 1,838.50 3,975.64 5,961,224.19 564,631.17 2.71 1,366.79 MWD+IFR-AK-CAZ-SC(3) 6,644.01 80.75 92.73 3,744.35 3,637.82 1,835.15 4,069.67 5,961,221.60 564,725.21 2.91 1,433.37 MWD+IFR-AK-CAZ-SC(3) 6,738.77 82.33 94.65 3,758.29 3,651.76 1,829.11 4,163.20 5,961,216.32 564,818.78 2.61 1,501.56 MWD+IFR-AK-CAZ-SC(3) 6,833.32 83.18 99.01 3,770.22 3,663.69 1,817.96 4,256.30 5,961,205.92 564,911.96 4.66 1,573.22 MWD+IFR-AK-CAZ-SC(3) 6,928.37 84.24 102.96 3,780.64 3,674.11 1,799.96 4,349.03 5,961,188.67 565,004.82 4.28 1,649.63 MW D+I FR-AK-CAZ-SC(3) 6,973.47 84.57 106.20 3,785.03 3,678.50 1,788.66 4,392.46 5,961,177.72 565,048.34 7.19 1,687.51 MWD+IFR-AK-CAZ-SC(3) 7,022.57 84.84 108.64 3,789.57 3,683.04 1,774.02 4,439.11 5,961,163.46 565,095.10 4.98 1,730.03 MWD+IFR-AK-CAZ-SC(3) 7,117.86 85.35 113.20 3,797.72 3,691.19 1,740.13 4,527.77 5,961,130.29 565,184.02 4.80 1,815.28 MW D+I FR-AK-CAZ-SC(3) 7,212.95 86.30 117.24 3,804.64 3,698.11 1,699.73 4,613.54 5,961,090.59 565,270.11 4.35 1,903.33 MW D+I FR-AK-CAZ-SC(3) 7,307.97 85.96 121.49 3,811.06 3,704.53 1,653.25 4,696.15 5,961,044.78 565,353.08 4.48 1,993.65 MW D+I FR-AK-CAZ-SC(3) 7,403.49 85.39 126.26 3,818.27 3,711.74 1,600.18 4,775.20 5,960,992.35 565,432.55 5.02 2,086.38 MWD+IFR-AK-CAZ-SC(3) 7,497.74 84.54 130.57 3,826.54 3,720.01 1,541.86 4,848.75 5,960,934.64 565,506.56 4.64 2,179.20 MW D+I FR-AK-CAZ-SC(3) 7,592.16 84.26 134.05 3,835.76 3,729.23 1,478.61 4,918.23 5,960,871.96 565,576.54 3.68 2,272.84 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 I0:09:41AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 7,687.77 84.58 136.64 3,845.06 3,738.53 1,410.93 4,985.11 5,960,804.82 565,643.95 2.72 2,367.94 MWD+IFR-AK-CAZ-SC(3) 7,731.41 84.85 137.26 3,849.08 3,742.55 1,379.18 5,014.77 5,960,773.31 565,673.87 1.54 2,411.40 MWD+IFR-AK-CAZ-SC(3) 7,796.50 86.07 137.30 3,854.23 3,747.70 1,331.51 5,058.79 5,960,726.00 565,718.27 1.88 2,476.28 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 7-5/8"x 9-7/8" 7,823.00 86.57 137.32 3,855.93 3,749.40 1,312.07 5,076.72 5,960,706.71 565,736.35 1.88 2,502.73 MWD+IFR-AK-CAZ-SC(4) 7,890.37 88.84 140.53 3,858.63 3,752.10 1,261.33 5,120.94 5,960,656.34 565,780.98 5.83 2,569.99 MWD+IFR-AK-CAZ-SC(4) 7,985.15 90.07 140.70 3,859.53 3,753.00 1,188.08 5,181.07 5,960,583.58 565,841.70 1.31 2,664.58 MWD+IFR-AK-CAZ-SC(4) 8,079.71 92.17 144.81 3,857.68 3,751.15 1,112.84 5,238.28 5,960,508.82 565,899.50 4.88 2,758.62 MWD+IFR-AK-CAZ-SC(4) 8,174.57 90.66 146.36 3,855.34 3,748.81 1,034.61 5,291.87 5,960,431.03 565,953.72 2.28 2,852.38 MWD+IFR-AK-CAZ-SC(4) 8,268.99 89.66 148.55 3,855.07 3,748.54 955.02 5,342.66 5,960,351.86 566,005.15 2.55 2,945.23 MWD+IFR-AK-CAZ-SC(4) 8,364.29 89.73 150.99 3,855.58 3,749.05 872.69 5,390.64 5,960,269.93 566,053.78 2.56 3,038.16 MWD+IFR-AK-CAZ-SC(4) 8,459.42 89.28 152.33 3,856.40 3,749.87 788.97 5,435.79 5,960,186.58 566,099.61 1.49 3,130.19 MWD+IFR-AK-CAZ-SC(4) 8,553.21 89.59 153.95 3,857.33 3,750.80 705.30 5,478.17 5,960,103.27 566,142.65 1.76 3,220.27 MWD+IFR-AK-CAZ-SC(4) 8,648.67 89.87 151.95 3,857.78 3,751.25 620.29 5,521.58 5,960,018.62 566,186.74 2.12 3,312.05 MWD+IFR-AK-CAZ-SC(4) 8,743.70 89.66 149.67 3,858.17 3,751.64 537.34 5,567.92 5,959,936.05 566,233.75 2.41 3,404.33 MWD+IFR-AK-CAZ-SC(4) 8,838.00 88.91 147.61 3,859.34 3,752.81 456.82 5,616.99 5,959,855.94 566,283.46 2.32 3,496.68 MWD+IFR-AK-CAZ-SC(4) 8,932.53 89.28 146.60 3,860.84 3,754.31 377.46 5,668.32 5,959,777.00 566,335.42 1.14 3,589.73 MWD+IFR-AK-CAZ-SC(4) 9,027.23 89.35 146.53 3,861.97 3,755.44 298.44 5,720.49 5,959,698.41 566,388.23 0.10 3,683.10 MWD+IFR-AK-CAZ-SC(4) 9,122.96 89.90 150.25 3,862.60 3,756.07 216.93 5,770.66 5,959,617.32 566,439.05 3.93 3,776.93 MWD+IFR-AK-CAZ-SC(4) 9,217.80 89.25 152.16 3,863.30 3,756.77 133.82 5,816.34 5,959,534.59 566,485.39 2.13 3,868.86 MWD+IFR-AK-CAZ-SC(4) 9,312.74 89.94 155.90 3,863.97 3,757.44 48.49 5,857.90 5,959,449.60 566,527.64 4.01 3,959.62 MWD+IFR-AK-CAZ-SC(4) 9,407.81 89.70 155.40 3,864.27 3,757.74 -38.13 5,897.10 5,959,363.32 566,567.53 0.58 4,049.70 MWD+IFR-AK-CAZ-SC(4) 9,502.13 90.28 154.15 3,864.29 3,757.76 -123.45 5,937.30 5,959,278.33 566,608.41 1.46 4,139.51 MWD+IFR-AK-CAZ-SC(4) 9,597.40 90.69 153.94 3,863.48 3,756.95 -209.11 5,978.99 5,959,193.02 566,650.79 0.48 4,230.59 MWD+IFR-AK-CAZ-SC(4) 9,691.74 90.69 153.15 3,862.34 3,755.81 -293.56 6,021.02 5,959,108.91 566,693.49 0.84 4,321.02 MWD+IFR-AK-CAZ-SC(4) 9,786.19 90.18 152.31 3,861.63 3,755.10 -377.51 6,064.29 5,959,025.32 566,737.44 1.04 4,411.93 MWD+IFR-AK-CAZ-SC(4) 9,880.93 89.49 150.80 3,861.90 3,755.37 -460.81 6,109.41 5,958,942.40 566,783.23 1.75 4,503.63 MWD+IFR-AK-CAZ-SC(4) 9,976.50 89.32 154.81 3,862.89 3,756.36 -545.79 6,153.08 5,958,857.78 566,827.58 4.20 4,595.56 MWD+IFR-AK-CAZ-SC(4) 10,070.99 90.31 158.81 3,863.20 3,756.67 -632.63 6,190.28 5,958,771.26 566,865.47 4.36 4,684.44 MWD+IFR-AK-CAZ-SC(4) 10,166.30 90.31 161.27 3,862.68 3,756.15 -722.21 6,222.81 5,958,681.95 566,898.72 2.58 4,772.14 MWD+IFR-AK-CAZ-SC(4) 10,261.14 90.18 164.77 3,862.28 3,755.75 -812.90 6,250.51 5,958,591.50 566,927.15 3.69 4,857.35 MWD+IFR-AK-CAZ-SC(4) 10,355.88 90.79 167.80 3,861.47 3,754.94 -904.92 6,272.96 5,958,499.67 566,950.34 3.26 4,939.97 MWD+IFR-AK-CAZ-SC(4) 10,451.55 91.38 170.66 3,859.66 3,753.13 -998.88 6,290.84 5,958,405.87 566,968.97 3.05 5,020.87 MWD+IFR-AK-CAZ-SC(4) 10,546.42 90.62 172.59 3,858.01 3,751.48 -1,092.72 6,304.65 5,958,312.15 566,983.54 2.19 5,098.93 MWD+IFR-AK-CAZ-SC(4) 10,641.28 90.62 174.97 3,856.98 3,750.45 -1,187.01 6,314.93 5,958,217.96 566,994.58 2.51 5,174.89 MWD+IFR-AK-CAZ-SC(4) 10,735.27 90.66 176.84 3,855.93 3,749.40 -1,280.75 6,321.64 5,958,124.28 567,002.05 1.99 5,248.03 MWD+IFR-AK-CAZ-SC(4) 10,829.85 90.72 177.70 3,854.79 3,748.26 -1,375.21 6,326.14 5,958,029.87 567,007.31 0.91 5,320.19 MWD+IFR-AK-CAZ-SC(4) 10,925.21 90.76 177.66 3,853.56 3,747.03 -1,470.49 6,330.00 5,957,934.64 567,011.94 0.06 5,392.50 MWD+IFR-AK-CAZ-SC(4) 11,020.27 90.69 177.04 3,852.36 3,745.83 -1,565.44 6,334.40 5,957,839.73 567,017.10 0.66 5,464.94 MWD+IFR-AK-CAZ-SC(4) 11,115.07 90.00 176.00 3,851.78 3,745.25 -1,660.06 6,340.15 5,957,745.17 567,023.62 1.32 5,538.06 MWD+IFR-AK-CAZ-SC(4) 11,210.11 90.24 175.62 3,851.59 3,745.06 -1,754.84 6,347.10 5,957,650.45 567,031.33 0.47 5,612.12 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 10:09:41AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1 D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,304.64 90.52 175.19 3,850.96 3,744.43 -1,849.07 6,354.67 5,957,556.30 567,039.66 0.54 5,686.20 MWD+IFR-AK-CAZ-SC(4) 11,400.44 90.59 176.77 3,850.03 3,743.50 -1,944.62 6,361.38 5,957,460.81 567,047.15 1.65 5,760.66 MWD+IFR-AK-CAZ-SC(4) 11,495.11 90.11 179.28 3,849.45 3,742.92 -2,039.23 6,364.65 5,957,366.25 567,051.17 2.70 5,832.08 MWD+IFR-AK-CAZ-SC(4) 11,589.77 90.48 178.35 3,848.96 3,742.43 -2,133.87 6,366.60 5,957,271.64 567,053.89 1.06 5,902.62 MWD+IFR-AK-CAZ-SC(4) 11,684.85 91.00 177.56 3,847.74 3,741.21 -2,228.88 6,370.00 5,957,176.67 567,058.05 0.99 5,974.42 MWD+IFR-AK-CAZ-SC(4) 11,779.54 91.55 178.45 3,845.63 3,739.10 -2,323.48 6,373.29 5,957,082.10 567,062.11 1.10 6,045.86 MW D+I FR-AK-CAZ-SC(4) 11,874.64 90.31 179.95 3,844.09 3,737.56 -2,418.56 6,374.62 5,956,987.05 567,064.21 2.05 6,116.30 MWD+IFR-AK-CAZ-SC(4) 11,969.01 89.94 182.20 3,843.88 3,737.35 -2,512.91 6,372.85 5,956,892.70 567,063.20 2.42 6,184.10 MWD+IFR-AK-CAZ-SC(4) 12,064.45 89.76 184.11 3,844.13 3,737.60 -2,608.20 6,367.60 5,956,797.38 567,058.72 2.01 6,250.20 MWD+1FR-AK-CAZ-SC(4) 12,159.07 91.07 183.49 3,843.44 3,736.91 -2,702.60 6,361.33 5,956,702.93 567,053.21 1.53 6,314.97 MWD+1FR-AK-CAZ-SC(4) 12,253.55 91.00 182.12 3,841.74 3,735.21 -2,796.95 6,356.70 5,956,608.56 567,049.35 1.45 6,380.82 MWD+I FR-AK-CAZ-SC(4) 12,349.01 91.51 181.66 3,839.65 3,733.12 -2,892.34 6,353.56 5,956,513.16 567,046.97 0.72 6,448.44 MWD+1FR-AK-CAZ-SC(4) 12,442.86 91.86 180.20 3,836.89 3,730.36 -2,986.13 6,352.03 5,956,419.36 567,046.21 1.60 6,515.99 MWD+IFR-AK-CAZ-SC(4) 12,538.02 91.79 178.87 3,833.86 3,727.33 -3,081.24 6,352.81 5,956,324.28 567,047.75 1.40 6,586.08 MWD+IFR-AK-CAZ-SC(4) 12,632.87 91.14 177.00 3,831.43 3,724.90 -3,175.99 6,356.22 5,956,229.56 567,051.93 2.09 6,657.71 MWD+IFR-AK-CAZ-SC(4) 12,728.19 90.38 177.71 3,830.17 3,723.64 -3,271.20 6,360.62 5,956,134.40 567,057.09 1.09 6,730.34 MWD+IFR-AK-CAZ-SC(4) 12,822.93 90.69 177.87 3,829.28 3,722.75 -3,365.86 6,364.27 5,956,039.78 567,061.51 0.37 6,802.06 MWD+IFR-AK-CAZ-SC(4) 12,917.38 90.66 178.16 3,828.17 3,721.64 -3,460.25 6,367.55 5,955,945.43 567,065.54 0.31 6,873.32 MW D+I FR-AK-CAZ-SC(4) 13,013.63 90.69 178.55 3,827.04 3,720.51 -3,556.45 6,370.31 5,955,849.26 567,069.08 0.41 6,945.57 MWD+IFR-AK-CAZ-SC(4) 13,104.67 91.31 177.91 3,825.45 3,718.92 -3,647.44 6,373.12 5,955,758.31 567,072.63 0.98 7,014.02 MWD+IFR-AK-CAZ-SC(4) 13,199.74 92.23 178.21 3,822.51 3,715.98 -3,742.41 6,376.34 5,955,663.38 567,076.61 1.02 7,085.67 MWD+IFR-AK-CAZ-SC(4) 13,295.24 90.14 176.91 3,820.54 3,714.01 -3,837.79 6,380.40 5,955,568.04 567,081.45 2.58 7,158.21 MWD+1FR-AK-CAZ-SC(4) 13,390.34 90.28 174.30 3,820.19 3,713.66 -3,932.60 6,387.69 5,955,473.30 567,089.50 2.75 7,232.52 MWD+IFR-AK-CAZ-SC(4) 13,487.95 90.62 172.89 3,819.42 3,712.89 -4,029.60 6,398.58 5,955,376.41 567,101.17 1.49 7,310.88 MWD+IFR-AK-CAZ-SC(4) 13,583.64 90.86 170.87 3,818.18 3,711.65 -4,124.32 6,412.09 5,955,281.81 567,115.44 2.13 7,389.37 MWD+IFR-AK-CAZ-SC(4) 13,678.08 91.41 172.64 3,816.31 3,709.78 -4,217.76 6,425.63 5,955,188.49 567,129.74 1.96 7,466.94 MWD+IFR-AK-CAZ-SC(4) 13,773.15 90.72 175.42 3,814.55 3,708.02 -4,312.28 6,435.52 5,955,094.05 567,140.38 3.01 7,542.82 MWD+IFR-AK-CAZ-SC(4) 13,868.28 90.00 178.90 3,813.95 3,707.42 -4,407.28 6,440.23 5,954,999.11 567,145.86 3.74 7,615.51 MWD+IFR-AK-CAZSC(4) 13,963.30 90.76 179.57 3,813.32 3,706.79 -4,502.29 6,441.50 5,954,904.12 567,147.90 1.07 7,685.86 MW D+I FR-AK-CAZ-SC(4) 14,057.55 90.76 181.71 3,812.07 3,705.54 -4,596.52 6,440.44 5,954,809.90 567,147.61 2.27 7,754.05 MW D+I FR-AK-CAZ-SC(4) 14,152.85 90.90 184.12 3,810.69 3,704.16 -4,691.68 6,435.60 5,954,714.71 567,143.53 2.53 7,820.34 MWD+IFR-AK-CAZ-SC(4) 14,246.38 90.07 187.22 3,809.90 3,703.37 -4,784.74 6,426.36 5,954,621.59 567,135.04 3.43 7,882.10 MWD+IFR-AK-CAZ-SC(4) 14,341.56 90.69 189.05 3,809.26 3,702.73 -4,878.95 6,412.89 5,954,527.28 567,122.34 2.03 7,941.82 MW D+I FR-AK-CAZ-SC(4) 14,436.03 91.03 188.61 3,807.85 3,701.32 -4,972.29 . 6,398.39 5,954,433.83 567,108.59 0.59 8,000.20 MWD+IFR-AK-CAZ-SC(4) 14,532.50 91.75 187.79 3,805.51 3,698.98 -5,067.75 6,384.64 5,954,338.28 567,095.61 1.13 8,060.63 MWD+I FR-AK-CAZ-SC(4) 14,626.56 91.07 187.25 3,803.19 3,696.66 -5,160.97 6,372.33 5,954,244.97 567,084.06 0.92 8,120.41 MWD+IFR-AK-CAZ-SC(4) 14,719.82 90.62 184.71 3,801.82 3,695.29 -5,253.70 6,362.62 5,954,152.17 567,075.09 2.77 8,181.61 MW D+I FR-AK-CAZ-SC(4) 14,816.50 91.27 181.97 3,800.22 3,693.69 -5,350.19 6,356.99 5,954,055.64 567,070.24 2.91 8,248.34 MWD+IFR-AK-CIIAZ-SC(4) 14,908.36 91.27 180.70 3,798.19 3,691.66 -5,442.01 6,354.85 5,953,963.83 567,068.84 1.38 8,314.03 MWD+IFR-AK-GAZ-SC(4) 15,001.29 90.72 177.50 3,796.57 3,690.04 -5,534.90 6,356.31 5,953,870.96 567,071.05 3.49 8,382.96 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 10:09:41AM Page 6 COMPASS 5000.1 Build 74 • S . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuprauk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,095.57 91.07 174.74 3,795.10 3,688.57 -5,628.94 6,362.68 5,953,776.98 567,078.19 2.95 8,456.09 MWD+IFR-AK-CAZ-SC(4) 15,185.08 90.45 174.94 3,793.91 3,687.38 -5,718.08 6,370.73 5,953,687.92 567,086.96 0.73 8,526.77 MWD+IFR-AK-CAZ-SC(4) 15,233.18 90.62 176.67 3,793.46 3,686.93 -5,766.05 6,374.25 5,953,639.98 567,090.86 3.61 8,564.25 MWD+IFR-AK-CAZ-SC(4) 15,278.40 90.59 177.87 3,792.98 3,686.45 -5,811.21 6,376.40 5,953,594.84 567,093.38 2.65 8,598.75 MWD+IFR-AK-CAZ-SC(4) 15,322.73 90.83 178.70 3,792.43 3,685.90 -5,855.52 6,377.73 5,953,550.55 567,095.07 1.95 8,632.06 MWD+IFR-AK-CAZ-SC(4) 15,371.45 90.79 180.27 3,791.75 3,685.22 -5,904.23 6,378.17 5,953,501.85 567,095.90 3.22 8,667.98 MWD+IFR-AK-CAZ-SC(4) 15,464.30 90.31 179.48 3,790.85 3,684.32 -5,997.07 6,378.37 5,953,409.02 567,096.85 1.00 8,736.02 MWD+IFR-AK-CAZ-SC(4) 15,556.99 90.11 178.39 3,790.51 3,683.98 -6,089.75 6,380.09 5,953,316.37 567,099.32 1.20 8,804.97 MWD+IFR-AK-CAZ-SC(4) 15,649.47 90.83 177.74 3,789.76 3,683.23 -6,182.17 6,383.22 5,953,223.99 567,103.19 1.05 8,874.70 MWD+IFR-AK-CAZ-SC(4) 15,740.60 91.14 177.16 3,788.19 3,681.66 -6,273.20 6,387.27 5,953,133.01 567,107.98 0.72 8,944.03 MWD+IFR-AK-CAZ-SC(4) 15,832.70 90.24 178.00 3,787.08 3,680.55 -6,365.20 6,391.16 5,953,041.04 567,112.61 1.34 9,013.98 MWD+IFR-AK-CAZ-SC(4) 15,923.64 89.22 177.84 3,787.51 3,680.98 -6,456.08 6,394.46 5,952,950.20 567,116.64 1.14 9,082.69 MWD+IFR-AK-CAZ-SC(4) 16,015.37 88.43 176.14 3,789.39 3,682.86 -6,547.66 6,399.28 5,952,858.67 567,122.19 2.04 9,152.95 MWD+IFR-AK-CAZ-SC(4) 16,108.82 88.67 175.65 3,791.76 3,685.23 -6,640.84 6,405.96 5,952,765.56 567,129.63 0.58 9,225.66 MWD+IFR-AK-CAZ-SC(4) 16,200.40 88.43 175.66 3,794.07 3,687.54 -6,732.13 6,412.90 5,952,674.34 567,137.31 0.26 9,297.15 MWD+IFR-AK-CAZ-SC(4) 16,292.91 90.62 178.19 3,794.84 3,688.31 -6,824.49 6,417.86 5,952,582.03 567,143.01 3.62 9,368.09 MWD+IFR-AK-CAZ-SC(4) 16,385.49 90.62 179.07 3,793.84 3,687.31 -6,917.04 6,420.07 5,952,489.51 567,145.97 0.95 9,437.28 MWD+IFR-AK-CAZ-SC(4) 16,412.21 90.66 178.12 3,793.54 3,687.01 -6,943.75 6,420.73 5,952,462.81 567,146.84 3.56 9,457.26 MWD+IFR-AK-CAZ-SC(4) 16,462.00 90.66 178.12 3,792.97 3,686.44 -6,993.51 6,422.36 5,952,413.07 567,148.88 0.00 9,494.77 NOT an Aedes Survey 4 1/2"x 6-3/4" 16,472.00 90.66 178.12 3,792.85 3,686.32 -7,003.50 6,422.69 5,952,403.08 567,149.29 0.00 9,502.30 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets anchor well position objectives have been achieved. El Yes El No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates p Declination & Convergence Q GRS Survey Corrections Survey Tool Codes Dg9aly sigol by Vincennt Osa DN:sfrYnrare Osaa Vincent Osara SLB DE: Dal.2015D7.151a2300 9e OD' asipodUlm Itaord `' Kelse Hallford mKa+m.saa..luaaa.°-uneytwra u..cua9u.. Client Representative: 7 ` 'ffOWimlsmlcl2, ne Date: 15-Jul-2015 7/15/2015 10:09:41AM Page 7 COMPASS 5000.1 Build 74 • S 24139 26070 RECEIVED JUL 2 4 2015 FINAL 400( ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D-146 Definitive Survey Report 15 July, 2015 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1D-146 Well Position +N/-S 0.00 usft Northing: 5,959,105.33 usfi Latitude: 70° 17'57.193 N +E/-W 0.00 usft Easting: 1,700,702.85 usfi Longitude: 149°30'42.275 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 67.10 usft Wellbore 1D-146 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/22/2015 18.84 80.92 57,556 Design 1D-146 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.43 Vertical Section: Depth From(TVD) +NI-5 +E/-W Direction (usft) (usft) (usft) (°) 39.43 0.00 0.00 137.00 'Survey Program Date 7/15/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.00 466.00 1D-146 Srvy#1 GYD-GC-SS(1D-146) GYD-GC-SS Gyrodata gyro single shots 6/23/2015 8:2'. 495.29 2,898.04 1D-146 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 8:31 2,988.78 7,731.41 1D-146 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/24/2015 12:2 7,823.00 16,412.21 1D-146 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/6/2015 10:42 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) (°I1001 (ft) Survey Tool Name 39.43 0.00 0.00 39.43 -67.10 0.00 0.00 5,959,105.33 1,700,702.85 0.00 0.00 UNDEFINED 80.00 0.16 177.50 80.00 -26.53 -0.06 0.00 5,959,105.28 1,700,702.85 0.39 0.04 GYD-GC-SS(1) 121.00 0.14 188.79 121.00 14.47 -0.16 0.00 5,959,105.17 1,700,702.84 0.09 0.12 GYD-GC-SS(1) 158.00 0.24 182.95 158.00 51.47 -0.28 -0.01 5,959,105.05 1,700,702.83 0.27 0.20 GYD-GC-SS(1) NOT an AeNd Survey 20"x 34" 216.00 0.39 179.66 216.00 109.47 -0.60 -0.02 5,959,104.73 1,700,702.83 0.27 0.43 GYD-GC-SS(1) 275.00 0.57 164.33 275.00 168.47 -1.08 0.06 5,959,104.25 1,700,702.92 0.37 0.84 GYD-GC-SS(1) 372.00 1.50 139.43 371.98 265.45 -2.51 1.02 5,959,102.83 1,700,703.88 1.04 2.53 GYD-GC-SS(1) 466.00 2.49 129.64 465.92 359.39 -4.75 3.39 5,959,100.61 1,700,706.27 1.11 5.79 GYD-GC-SS(1) 495.29 3.02 124.45 495.18 388.65 -5.59 4.52 5,959,099.78 1,700,707.41 2.00 7.17 MWD+IFR-AK-CAZ-SC(2) 588.03 4.24 115.21 587.73 481.20 -8.44 9.63 5,959,096.98 1,700,712.54 1.45 12.74 MWD+IFR-AK-CAZ-SC(2) 7/15/2015 8:34:54AM Page 2 COMPASS 5000.1 Build 74 • S Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 681.75 4.78 111.26 681.16 574.63 -11.33 16.41 5,959,094.14 1,700,719.34 0.66 19.47 MWD+IFR-AK-CAZ-SC(2) 776.91 5.10 105.70 775.97 669.44 -13.91 24.17 5,959,091.62 1,700,727.13 0.60 26.66 MWD+IFR-AK-CAZ-SC(2) 871.83 6.91 106.42 870.36 763.83 -16.67 33.71 5,959,088.94 1,700,736.69 1.91 35.18 MWD+IFR-AK-CAZ-SC(2) 970.63 10.80 104.09 967.97 861.44 -20.60 48.40 5,959,085.13 1,700,751.40 3.95 48.07 MWD+IFR-AK-CAZ-SC(2) 1,060.02 11.78 101.78 1,055.63 949.10 -24.50 65.45 5,959,081.36 1,700,768.49 1.21 62.56 MWD+IFR-AK-CAZ-SC(2) 1,112.51 11.50 102.87 1,107.04 1,000.51 -26.76 75.80 5,959,079.18 1,700,778.85 0.68 71.27 MWD+IFR-AK-CAZ-SC(2) 1,155.54 12.23 103.88 1,149.15 1,042.62 -28.81 84.41 5,959,077.21 1,700,787.47 1.76 78.64 MWD+IFR-AK-CAZ-SC(2) 1,250.98 14.85 104.07 1,241.93 1,135.40 -34.21 106.09 5,959,071.98 1,700,809.19 2.75 97.37 MWD+IFR-AK-CAZ-SC(2) 1,344.66 17.52 102.12 1,331.89 1,225.36 -40.09 131.52 5,959,066.31 1,700,834.67 2.91 119.02 MWD+IFR-AK-CAZ-SC(2) 1,439.69 20.51 97.07 1,421.73 1,315.20 -45.14 162.04 5,959,061.50 1,700,865.22 3.59 143.53 MWD+IFR-AK-CAZ-SC(2) 1,534.57 23.74 93.15 1,509.61 1,403.08 -48.24 197.61 5,959,058.69 1,700,900.82 3.74 170.05 MWD+IFR-AK-CAZ-SC(2) 1,628.39 27.45 88.85 1,594.22 1,487.69 -48.84 238.11 5,959,058.41 1,700,941.32 4.42 198.11 MWD+IFR-AK-CAZ-SC(2) 1,722.34 27.52 87.55 1,677.57 1,571.04 -47.48 281.44 5,959,060.12 1,700,984.63 0.64 226.67 MWD+IFR-AK-CAZ-SC(2) 1,817.50 31.97 81.11 1,760.19 1,653.66 -42.64 328.33 5,959,065.33 1,701,031.48 5.75 255.11 MWD+IFR-AK-CAZ-SC(2) 1,867.23 33.16 76.88 1,802.11 1,695.58 -37.52 354.59 5,959,070.66 1,701,057.69 5.16 269.27 MWD+IFR-AK-CAZ-SC(2) 1,912.16 33.17 75.32 1,839.72 1,733.19 -31.62 378.45 5,959,076.76 1,701,081.50 1.90 281.23 MWD+IFR-AK-CAZ-SC(2) 2,007.73 34.99 69.38 1,918.89 1,812.36 -15.34 429.41 5,959,093.45 1,701,132.32 3.97 304.07 MWD+IFR-AK-CAZ-SC(2) 2,101.57 37.97 64.91 1,994.35 1,887.82 6.39 480.75 5,959,115.58 1,701,183.48 4.25 323.20 MWD+IFR-AK-CAZ-SC(2) 2,197.38 39.13 62.81 2,069.28 1,962.75 32.70 534.34 5,959,142.32 1,701,236.85 1.83 340.50 MWD+IFR-AK-CAZ-SC(2) 2,291.79 42.43 60.59 2,140.77 2,034.24 61.96 588.60 5,959,172.01 1,701,290.87 3.82 356.11 MWD+IFR-AK-CAZ-SC(2) 2,387.77 44.47 59.71 2,210.44 2,103.91 94.82 645.84 5,959,205.33 1,701,347.84 2.22 371.11 MWD+IFR-AK-CAZ-SC(2) 2,481.16 48.90 58.56 2,274.49 2,167.96 129.70 704.14 5,959,240.66 1,701,405.85 4.83 385.37 MWD+IFR-AK-CAZ-SC(2) 2,574.34 51.86 58.30 2,333.91 2,227.38 167.27 765.28 5,959,278.72 1,701,466.69 3.18 399.59 MWD+IFR-AK-CAZ-SC(2) 2,668.73 53.77 58.19 2,390.95 2,284.42 206.85 829.22 5,959,318.81 1,701,530.30 2.03 414.25 MWD+IFR-AK-CAZ-SC(2) 2,764.04 59.97 56.48 2,443.02 2,336.49 249.94 896.35 5,959,362.43 1,701,597.08 6.68 428.52 MWD+IFR-AK-CAZ-SC(2) 2,809.43 64.01 56.25 2,464.33 2,357.80 272.13 929.71 5,959,384.89 1,701,630.25 8.91 435.04 MWD+IFR-AK-CAZ-SC(2) 2,858.60 65.87 55.91 2,485.16 2,378.63 296.99 966.67 5,959,410.04 1,701,667.01 3.83 442.07 MWD+IFR-AK-CAZ-SC(2) 2,898.04 66.55 54.06 2,501.07 2,394.54 317.69 996.22 5,959,430.98 1,701,696.39 4.63 447.08 MWD+IFR-AK-CAZ-SC(2) 2,961.00 67.03 53.55 2,525.88 2,419.35 351.86 1,042.92 5,959,465.52 1,701,742.81 1.06 453.93 MWD+IFR-AK-CAZ-SC(3) MDT 10 3/4"x 13-1/2 al &a' 2,988.78 67.24 53.33 2,536.68 2,430.15 367.11 1,063.48 5,959,480.93 1,701,763.25 1.06 456.81 MWD+IFR-AK-CAZ-SC(3) 3,040.58 67.93 53.62 2,556.43 2,449.90 395.61 1,101.96 5,959,509.73 1,701,801.49 1.43 462.21 MWD+IFR-AK-CAZ-SC(3) 3,135.94 70.91 52.93 2,589.95 2,483.42 448.99 1,173.51 5,959,563.68 1,701,872.60 3.20 471.96 MWD+IFR-AK-CAZ-SC(3) 3,230.50 73.39 52.28 2,618.93 2,512.40 503.65 1,245.01 5,959,618.91 1,701,943.65 2.70 480.74 MWD+IFR-AK-CAZ-SC(3) 3,325.04 72.98 50.58 2,646.28 2,539.75 560.07 1,315.76 5,959,675.89 1,702,013.94 1.78 487.74 MWD+IFR-AK-CAZ-SC(3) 3,420.29 72.72 49.32 2,674.37 2,567.84 618.63 1,385.43 5,959,735.00 1,702,083.13 1.29 492.42 MWD+IFR-AK-CAZ-SC(3) 3,515.37 72.63 49.10 2,702.68 2,596.15 677.93 1,454.15 5,959,794.84 1,702,151.37 0.24 495.92 MWD+IFR-AK-CAZ-SC(3) 3,609.44 72.39 48.78 2,730.95 2,624.42 736.86 1,521.80 5,959,854.31 1,702,218.54 0.41 498.96 MWD+IFR-AK-CAZ-SC(3) 3,704.43 72.20 50.15 2,759.84 2,653.31 795.67 1,590.57 5,959,913.67 1,702,286.83 1.39 502.85 MWD+IFR-AK-CAZ-SC(3) 3,799.20 70.53 50.75 2,790.12 2,683.59 852.85 1,659.81 5,959,971.39 1,702,355.60 1.86 508.25 MWD+IFR-AK-CAZ-SC(3) 3,894.52 69.62 53.19 2,822.61 2,716.08 908.06 1,730.39 5,960,027.16 1,702,425.73 2.59 516.01 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 8:34:54AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 10 Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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 3,988.94 69.71 52.76 2,855.42 2,748.89 961.37 1,801.07 5,960,081.03 1,702,495.97 0.44 525.22 MWD+IFR-AK-CAZ-SC(3) 4,084.38 68.50 52.52 2,889.46 2,782.93 1,015.48 1,871.94 5,960,135.70 1,702,566.40 1.29 533.99 MWD+IFR-AK-CAZ-SC(3) 4,179.59 68.27 51.95 2,924.54 2,818.01 1,069.69 1,941.92 5,960,190.46 1,702,635.93 0.61 542.06 MW D+I FR-AK-CAZ-SC(3) 4,274.27 68.83 49.82 2,959.16 2,852.63 1,125.28 2,010.28 5,960,246.60 1,702,703.84 2.18 548.03 MW D+I FR-AK-CAZ-SC(3) 4,368.76 68.88 50.19 2,993.25 2,886.72 1,181.92 2,077.80 5,960,303.77 1,702,770.89 0.37 552.65 MWD+1FR-AK-CAZ-SC(3) 4,463.80 68.68 52.46 3,027.65 2,921.12 1,237.28 2,146.96 5,960,359.68 1,702,839.60 2.24 559.33 MWD+IFR-AK-CAZ-SC(3) 4,558.15 68.93 55.18 3,061.77 2,955.24 1,289.20 2,217.95 5,960,412.17 1,702,910.17 2.70 569.78 MWD+IFR-AK-CAZ-SC(3) 4,653.14 69.31 56.91 3,095.63 2,989.10 1,338.77 2,291.57 5,960,462.32 1,702,983.38 1.75 583.73 MWD+IFR-AK-CAZ-SC(3) 4,748.17 69.17 59.14 3,129.31 3,022.78 1,385.82 2,366.94 5,960,509.97 1,703,058.36 2.20 600.72 MWD+IFR-AK-CAZ-SC(3) 4,842.93 69.24 60.42 3,162.96 3,056.43 1,430.41 2,443.49 5,960,555.16 1,703,134.54 1.26 620.32 MWD+IFR-AK-CAZ-SC(3) 4,937.69 69.20 62.09 3,196.58 3,090.05 1,473.01 2,521.16 5,960,598.39 1,703,211.87 1.65 642.13 MWD+I FR-AK-CAZ-SC(3) 5,032.74 69.50 63.72 3,230.10 3,123.57 1,513.52 2,600.34 5,960,639.52 1,703,290.71 1.64 666.51 MWD+1FR-AK-CAZ-SC(3) 5,127.24 68.95 64.83 3,263.62 3,157.09 1,551.87 2,679.94 5,960,678.51 1,703,369.99 1.24 692.74 MWD+IFR-AK-CAZ-SC(3) 5,222.04 69.19 66.13 3,297.49 3,190.96 1,588.62 2,760.49 5,960,715.90 1,703,450.24 1.31 720.81 MWD+IFR-AK-CAZ-SC(3) 5,317.25 69.21 67.12 3,331.30 3,224.77 1,623.93 2,842.19 5,960,751.86 1,703,531.65 0.97 750.70 MWD+IFR-AK-CAZ-SC(3) 5,411.11 69.28 67.71 3,364.56 3,258.03 1,657.64 2,923.23 5,960,786.21 1,703,612.40 0.59 781.32 MWD+IFR-AK-CAZ-SC(3) 5,505.57 69.53 69.06 3,397.79 3,291.26 1,690.21 3,005.43 5,960,819.44 1,703,694.33 1.36 813.56 MW D+I FR-AK-CAZ-SC(3) 5,599.93 69.14 70.94 3,431.09 3,324.56 1,720.41 3,088.39 5,960,850.30 1,703,777.04 1.91 848.05 MW D+I FR-AK-CAZ-SC(3) 5,694.11 69.17 73.53 3,464.61 3,358.08 1,747.26 3,172.20 5,960,877.82 1,703,860.62 2.57 885.57 MW D+I FR-AK-CAZ-SC(3) 5,789.14 69.60 75.49 3,498.07 3,391.54 1,771.01 3,257.91 5,960,902.25 1,703,946.13 1.98 926.66 MW D+I FR-AK-CAZ-SC(3) 5,884.45 70.26 79.01 3,530.79 3,424.26 1,790.76 3,345.21 5,960,922.70 1,704,033.26 3.54 971.75 MWD+IFR-AK-CAZ-SC(3) 5,979.24 70.60 79.97 3,562.54 3,456.01 1,807.05 3,433.02 5,960,939.69 1,704,120.93 1.02 1,019.73 MWD+1FR-AK-CAZ-SC(3) 6,073.97 71.45 82.89 3,593.34 3,486.81 1,820.39 3,521.59 5,960,953.74 1,704,209.38 3.05 1,070.37 MWD+IFR-AK-CAZ-SC(3) 6,169.63 71.67 85.65 3,623.61 3,517.08 1,829.45 3,611.88 5,960,963.52 1,704,299.59 2.75 1,125.32 MWD+IFR-AK-CAZ-SC(3) 6,264.37 71.69 87.30 3,653.39 3,546.86 1,834.98 3,701.64 5,960,969.77 1,704,389.29 1.65 1,182.50 MW D+I FR-AK-CAZ-SC(3) 6,358.54 73.75 88.48 3,681.36 3,574.83 1,838.28 3,791.50 5,960,973.80 1,704,479.11 2.49 1,241.36 MWD+I FR-AK-CAZ-SC(3) 6,452.61 76.13 89.92 3,705.80 3,599.27 1,839.54 3,882.32 5,960,975.79 1,704,569.91 2.93 1,302.38 MWD+IFR-AK-CAZ-SC(3) 6,548.32 78.32 91.35 3,726.97 3,620.44 1,838.50 3,975.64 5,960,975.50 1,704,663.23 2.71 1,366.79 MWD+IFR-AK-CAZ-SC(3) 6,644.01 80.75 92.73 3,744.35 3,637.82 1,835.15 4,069.67 5,960,972.90 1,704,757.27 2.91 1,433.37 MWD+IFR-AK-CAZ-SC(3) 6,738.77 82.33 94.65 3,758.29 3,651.76 1,829.11 4,163.20 5,960,967.61 1,704,850.84 2.61 1,501.56 MWD+IFR-AK-CAZ-SC(3) 6,833.32 83.18 99.01 3,770.22 3,663.69 1,817.96 4,256.30 5,960,957.21 1,704,944.02 4.66 1,573.22 MWD+IFR-AK-CAZ-SC(3) 6,928.37 84.24 102.96 3,780.64 3,674.11 1,799.96 4,349.03 5,960,939.95 1,705,036.88 4.28 1,649.63 MWD+I FR-AK-CAZ-SC(3) 6,973.47 84.57 106.20 3,785.03 3,678.50 1,788.66 4,392.46 5,960,929.00 1,705,080.40 7.19 1,687.51 MWD+IFR-AK-CAZ-SC(3) 7,022.57 84.84 108.64 3,789.57 3,683.04 1,774.02 4,439.11 5,960,914.74 1,705,127.15 4.98 1,730.03 MWD+IFR-AK-CAZ-SC(3) 7,117.86 85.35 113.20 3,797.72 3,691.19 1,740.13 4,527.77 5,960,881.57 1,705,216.07 4.80 1,815.28 MWD+IFR-AK-CAZ-SC(3) 7,212.95 86.30 117.24 3,804.64 3,698.11 1,699.73 4,613.54 5,960,841.86 1,705,302.16 4.35 1,903.33 MWD+IFR-AK-CAZ-SC(3) 7,307.97 85.96 121.49 3,811.06 3,704.53 1,653.25 4,696.15 5,960,796.05 1,705,385.13 4.48 1,993.65 MWD+IFR-AK-CAZ-SC(3) 7,403.49 85.39 126.26 3,818.27 3,711.74 1,600.18 4,775.20 5,960,743.62 1,705,464.60 5.02 2,086.38 MWD+IFR-AK-CAZ-SC(3) 7,497.74 84.54 130.57 3,826.54 3,720.01 1,541.86 4,848.75 5,960,685.89 1,705,538.61 4.64 2,179.20 MWD+IFR-AK-CAZ-SC(3) 7,592.16 84.26 134.05 3,835.76 3,729.23 1,478.61 4,918.23 5,960,623.22 1,705,608.59 3.68 2,272.84 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 8:34:54AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 10 Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 7,687.77 84.58 136.64 3,845.06 3,738.53 1,410.93 4,985.11 5,960,556.08 1,705,675.99 2.72 2,367.94 MWD+IFR-AK-CAZ-SC(3) 7,731.41 84.85 137.26 3,849.08 3,742.55 1,379.18 5,014.77 5,960,524.56 1,705,705.91 1.54 2,411.40 MWD+IFR-AK-CAZ-SC(3) 7,796.50 86.07 137.30 3,854.23 3,747.70 1,331.51 5,058.79 5,960,477.25 1,705,750.30 1.88 2,476.28 MWD+IFR-AK-CAZ-SC(4) NOT oaMal gamy 7-5/8"x 9-718" 7,823.00 86.57 137.32 3,855.93 3,749.40 1,312.07 5,076.72 5,960,457.96 1,705,768.39 1.88 2,502.73 MWD+IFR-AK-CAZ-SC(4) 7,890.37 88.84 140.53 3,858.63 3,752.10 1,261.33 5,120.94 5,960,407.58 1,705,813.01 5.83 2,569.99 MWD+IFR-AK-CAZ-SC(4) 7,985.15 90.07 140.70 3,859.53 3,753.00 1,188.08 5,181.07 5,960,334.83 1,705,873.72 1.31 2,664.58 MWD+IFR-AK-CAZ-SC(4) 8,079.71 92.17 144.81 3,857.68 3,751.15 1,112.84 5,238.28 5,960,260.05 1,705,931.52 4.88 2,758.62 MWD+IFR-AK-CAZ-SC(4) 8,174.57 90.66 146.36 3,855.34 3,748.81 1,034.61 5,291.87 5,960,182.27 1,705,985.74 2.28 2,852.38 MWD+IFR-AK-CAZ-SC(4) 8,268.99 89.66 148.55 3,855.07 3,748.54 955.02 5,342.66 5,960,103.10 1,706,037.16 2.55 2,945.23 MWD+IFR-AK-CAZ-SC(4) 8,364.29 89.73 150.99 3,855.58 3,749.05 872.69 5,390.64 5,960,021.16 1,706,085.79 2.56 3,038.16 MWD+IFR-AK-CAZ-SC(4) 8,459.42 89.28 152.33 3,856.40 3,749.87 788.97 5,435.79 5,959,937.81 1,706,131.61 1.49 3,130.19 MWD+IFR-AK-CAZ-SC(4) 8,553.21 89.59 153.95 3,857.33 3,750.80 705.30 5,478.17 5,959,854.50 1,706,174.65 1.76 3,220.27 MWD+IFR-AK-CAZ-SC(4) 8,648.67 89.87 151.95 3,857.78 3,751.25 620.29 5,521.58 5,959,769.84 1,706,218.74 2.12 3,312.05 MWD+IFR-AK-CAZ-SC(4) 8,743.70 89.66 149.67 3,858.17 3,751.64 537.34 5,567.92 5,959,687.27 1,706,265.74 2.41 3,404.33 MWD+IFR-AK-CAZ-SC(4) 8,838.00 88.91 147.61 3,859.34 3,752.81 456.82 5,616.99 5,959,607.16 1,706,315.45 2.32 3,496.68 MWD+IFR-AK-CAZ-SC(4) 8,932.53 89.28 146.60 3,860.84 3,754.31 377.46 5,668.32 5,959,528.22 1,706,367.41 1.14 3,589.73 MWD+IFR-AK-CAZ-SC(4) 9,027.23 89.35 146.53 3,861.97 3,755.44 298.44 5,720.49 5,959,449.63 1,706,420.21 0.10 3,683.10 MWD+IFR-AK-CAZ-SC(4) 9,122.96 89.90 150.25 3,862.60 3,756.07 216.93 5,770.66 5,959,368.53 1,706,471.03 3.93 3,776.93 MWD+IFR-AK-CAZ-SC(4) 9,217.80 89.25 152.16 3,863.30 3,756.77 133.82 5,816.34 5,959,285.80 1,706,517.36 2.13 3,868.86 MWD+IFR-AK-CAZ-SC(4) 9,312.74 89.94 155.90 3,863.97 3,757.44 48.49 5,857.90 5,959,200.81 1,706,559.61 4.01 3,959.62 MWD+IFR-AK-CAZ-SC(4) 9,407.81 89.70 155.40 3,864.27 3,757.74 -38.13 5,897.10 5,959,114.52 1,706,599.50 0.58 4,049.70 MWD+IFR-AK-CAZ-SC(4) 9,502.13 90.28 154.15 3,864.29 3,757.76 -123.45 5,937.30 5,959,029.53 1,706,640.37 1.46 4,139.51 MWD+IFR-AK-CAZ-SC(4) 9,597.40 90.69 153.94 3,863.48 3,756.95 -209.11 5,978.99 5,958,944.22 1,706,682.75 0.48 4,230.59 MWD+IFR-AK-CAZ-SC(4) 9,691.74 90.69 153.15 3,862.34 3,755.81 -293.56 6,021.02 5,958,860.11 1,706,725.45 0.84 4,321.02 MWD+IFR-AK-CAZ-SC(4) 9,786.19 90.18 152.31 3,861.63 3,755.10 -377.51 6,064.29 5,958,776.52 1,706,769.39 1.04 4,411.93 MWD+IFR-AK-CAZ-SC(4) 9,880.93 89.49 150.80 3,861.90 3,755.37 -460.81 6,109.41 5,958,693.59 1,706,815.17 1.75 4,503.63 MWD+IFR-AK-CAZ-SC(4) 9,976.50 89.32 154.81 3,862.89 3,756.36 -545.79 6,153.08 5,958,608.97 1,706,859.52 4.20 4,595.56 MWD+IFR-AK-CAZ-SC(4) 10,070.99 90.31 158.81 3,863.20 3,756.67 -632.63 6,190.28 5,958,522.44 1,706,897.41 4.36 4,684.44 MWD+IFR-AK-CAZ-SC(4) 10,166.30 90.31 161.27 3,862.68 3,756.15 -722.21 6,222.81 5,958,433.14 1,706,930.66 2.58 4,772.14 MWD+IFR-AK-CAZ-SC(4) 10,261.14 90.18 164.77 3,862.28 3,755.75 -812.90 6,250.51 5,958,342.68 1,706,959.07 3.69 4,857.35 MWD+IFR-AK-CAZ-SC(4) 10,355.88 90.79 167.80 3,861.47 3,754.94 -904.92 6,272.96 5,958,250.85 1,706,982.27 3.26 4,939.97 MWD+IFR-AK-CAZ-SC(4) 10,451.55 91.38 170.66 3,859.66 3,753.13 -998.88 6,290.84 5,958,157.05 1,707,000.89 3.05 5,020.87 MWD+IFR-AK-CAZ-SC(4) 10,546.42 90.62 172.59 3,858.01 3,751.48 -1,092.72 6,304.65 5,958,063.33 1,707,015.46 2.19 5,098.93 MWD+IFR-AK-CAZ-SC(4) 10,641.28 90.62 174.97 3,856.98 3,750.45 -1,187.01 6,314.93 5,957,969.14 1,707,026.49 2.51 5,174.89 MWD+IFR-AK-CAZ-SC(4) 10,735.27 90.66 176.84 3,855.93 3,749.40 -1,280.75 6,321.64 5,957,875.46 1,707,033.95 1.99 5,248.03 MWD+IFR-AK-CAZ-SC(4) 10,829.85 90.72 177.70 3,854.79 3,748.26 -1,375.21 6,326.14 5,957,781.05 1,707,039.21 0.91 5,320.19 MWD+IFR-AK-CAZ-SC(4) 10,925.21 90.76 177.66 3,853.56 3,747.03 -1,470.49 6,330.00 5,957,685.82 1,707,043.83 0.06 5,392.50 MWD+IFR-AK-CAZ-SC(4) 11,020.27 90.69 177.04 3,852.36 3,745.83 -1,565.44 6,334.40 5,957,590.91 1,707,048.99 0.66 5,464.94 MWD+IFR-AK-CAZ-SC(4) 11,115.07 90.00 176.00 3,851.78 3,745.25 -1,660.06 6,340.15 5,957,496.35 1,707,055.50 1.32 5,538.06 MWD+IFR-AK-CAZ-SC(4) 11,210.11 90.24 175.62 3,851.59 3,745.06 -1,754.84 6,347.10 5,957,401.63 1,707,063.21 0.47 5,612.12 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 8:34:54AM Page 5 COMPASS 5000.1 Build 74 • r . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 11,304.64 90.52 175.19 3,850.96 3,744.43 -1,849.07 6,354.67 5,957,307.48 1,707,071.53 0.54 5,686.20 MWD+IFR-AK-CAZ-SC(4) 11,400.44 90.59 176.77 3,850.03 3,743.50 -1,944.62 6,361.38 5,957,211.99 1,707,079.02 1.65 5,760.66 MWD+IFR-AK-CAZ-SC(4) 11,495.11 90.11 179.28 3,849.45 3,742.92 -2,039.23 6,364.65 5,957,117.43 1,707,083.04 2.70 5,832.08 MW D+I FR-AK-CAZ-SC(4) 11,589.77 90.48 178.35 3,848.96 3,742.43 -2,133.87 6,366.60 5,957,022.82 1,707,085.75 1.06 5,902.62 MW D+I FR-AK-CAZ-SC(4) 11,684.85 91.00 177.56 3,847.74 3,741.21 -2,228.88 6,370.00 5,956,927.84 1,707,089.91 0.99 5,974.42 MWD+1FR-AK-CAZ-SC(4) 11,779.54 91.55 178.45 3,845.63 3,739.10 -2,323.48 6,373.29 5,956,833.28 1,707,093.96 1.10 6,045.86 MWD+IFR-AK-CAZ-SC(4) 11,874.64 90.31 179.95 3,844.09 3,737.56 -2,418.56 6,374.62 5,956,738.22 1,707,096.05 2.05 6,116.30 MWD+IFR-AK-CAZ-SC(4) 11,969.01 89.94 182.20 3,843.88 3,737.35 -2,512.91 6,372.85 5,956,643.88 1,707,095.04 2.42 6,184.10 MWD+IFR-AK-CAZ-SC(4) 12,064.45 89.76 184.11 3,844.13 3,737.60 -2,608.20 6,367.60 5,956,548.56 1,707,090.55 2.01 6,250.20 MWD+IFR-AK-CAZ-SC(4) 12,159.07 91.07 183.49 3,843.44 3,736.91 -2,702.60 6,361.33 5,956,454.11 1,707,085.04 1.53 6,314.97 MW D+I FR-AK-CAZ-SC(4) 12,253.55 91.00 182.12 3,841.74 3,735.21 -2,796.95 6,356.70 5,956,359.74 1,707,081.17 1.45 6,380.82 MWD+IFR-AK-CAZ-SC(4) 12,349.01 91.51 181.66 3,839.65 3,733.12 -2,892.34 6,353.56 5,956,264.34 1,707,078.79 0.72 6,448.44 MWD+IFR-AK-CAZ-SC(4) 12,442.86 91.86 180.20 3,836.89 3,730.36 -2,986.13 6,352.03 5,956,170.54 1,707,078.02 1.60 6,515.99 MWD+1FR-AK-CAZ-SC(4) 12,538.02 91.79 178.87 3,833.86 3,727.33 -3,081.24 6,352.81 5,956,075.46 1,707,079.56 1.40 6,586.08 MW D+I FR-AK-CAZ-SC(4) 12,632.87 91.14 177.00 3,831.43 3,724.90 -3,175.99 6,356.22 5,955,980.74 1,707,083.73 2.09 6,657.71 MWD+IFR-AK-CAZ-SC(4) 12,728.19 90.38 177.71 3,830.17 3,723.64 -3,271.20 6,360.62 5,955,885.58 1,707,088.89 1.09 6,730.34 MWD+IFR-AK-CAZ-SC(4) 12,822.93 90.69 177.87 3,829.28 3,722.75 -3,365.86 6,364.27 5,955,790.96 1,707,093.31 0.37 6,802.06 MWD+IFR-AK-CAZ-SC(4) 12,917.38 90.66 178.16 3,828.17 3,721.64 -3,460.25 6,367.55 5,955,696.61 1,707,097.33 0.31 6,873.32 MWD+IFR-AK-CAZ-SC(4) 13,013.63 90.69 178.55 3,827.04 3,720.51 -3,556.45 6,370.31 5,955,600.44 1,707,100.87 0.41 6,945.57 MWD+IFR-AK-CAZSC(4) 13,104.67 91.31 177.91 3,825.45 3,718.92 -3,647.44 6,373.12 5,955,509.49 1,707,104.41 0.98 7,014.02 MWD+IFR-AK-CAZ-SC(4) 13,199.74 92.23 178.21 3,822.51 3,715.98 -3,742.41 6,376.34 5,955,414.56 1,707,108.39 1.02 7,085.67 MWD+I FR-AK-CAZ-SC(4) 13,295.24 90.14 176.91 3,820.54 3,714.01 -3,837.79 6,380.40 5,955,319.22 1,707,113.22 2.58 7,158.21 MW D+I FR-AK-CAZ-SC(4) 13,390.34 90.28 174.30 3,820.19 3,713.66 -3,932.60 6,387.69 5,955,224.48 1,707,121.26 2.75 7,232.52 MWD+IFR-AK-CAZ-SC(4) 13,487.95 90.62 172.89 3,819.42 3,712.89 -4,029.60 6,398.58 5,955,127.58 1,707,132.93 1.49 7,310.88 MWD+IFR-AK-CAZ-SC(4) 13,583.64 90.86 170.87 3,818.18 3,711.65 -4,124.32 6,412.09 5,955,032.99 1,707,147.20 2.13 7,389.37 MWD+1FR-AK-CAZ-SC(4) 13,678.08 91.41 172.64 3,816.31 3,709.78 -4,217.76 6,425.63 5,954,939.67 1,707,161.49 1.96 7,466.94 MWD+IFR-AK-CAZ-SC(4) 13,773.15 90.72 175.42 3,814.55 3,708.02 -4,312.28 6,435.52 5,954,845.23 1,707,172.13 3.01 7,542.82 MWD+IFR-AK-CAZ-SC(4) 13,868.28 90.00 178.90 3,813.95 3,707.42 -4,407.28 6,440.23 5,954,750.28 1,707,177.60 3.74 7,615.51 MW D+I FR-AK-CAZ-SC(4) 13,963.30 90.76 179.57 3,813.32 3,706.79 -4,502.29 6,441.50 5,954,655.30 1,707,179.64 1.07 7,685.86 MWD+IFR-AK-CAZ-SC(4) 14,057.55 90.76 181.71 3,812.07 3,705.54 -4,596.52 6,440.44 5,954,561.07 1,707,179.34 2.27 7,754.05 MWD+IFR-AK-CAZ-SC(4) 14,152.85 90.90 184.12 3,810.69 3,704.16 -4,691.68 6,435.60 5,954,465.88 1,707,175.26 2.53 7,820.34 MWD+IFR-AK-CAZ-SC(4) 14,246.38 90.07 187.22 3,809.90 3,703.37 -4,784.74 6,426.36 5,954,372.77 1,707,166.77 3.43 7,882.10 MWD+IFR-AK-CAZ-SC(4) 14,341.56 90.69 189.05 3,809.26 3,702.73 -4,878.95 6,412.89 5,954,278.45 1,707,154.06 2.03 7,941.82 MWD+IFR-AK-CAZ-SC(4) 14,436.03 91.03 188.61 3,807.85 3,701.32 -4,972.29 6,398.39 5,954,185.01 1,707,140.31 0.59 8,000.20 MWD+IFR-AK-CAZ-SC(4) 14,532.50 91.75 187.79 3,805.51 3,698.98 -5,067.75 6,384.64 5,954,089.46 1,707,127.32 1.13 8,060.63 MWD+IFR-AK-CAZ-SC(4) 14,626.56 91.07 187.25 3,803.19 3,696.66 -5,160.97 6,372.33 5,953,996.15 1,707,115.76 0.92 8,120.41 MW D+I FR-AK-CAZ-SC(4) 14,719.82 90.62 184.71 3,801.82 3,695.29 -5,253.70 6,362.62 5,953,903.35 1,707,106.79 2.77 8,181.61 MWD+IFR-AK-CAZ-SC(4) 14,816.50 91.27 181.97 3,800.22 3,693.69 -5,350.19 6,356.99 5,953,806.82 1,707,101.94 2.91 8,248.34 MWD+IFR-AK-CAZ-SC(4) 14,908.36 91.27 180.70 3,798.19 3,691.66 -5,442.01 6,354.85 5,953,715.01 1,707,100.53 1.38 8,314.03 MWD+IFR-AK-CAZ-SC(4) 15,001.29 90.72 177.50 3,796.57 3,690.04 -5,534.90 6,356.31 5,953,622.14 1,707,102.74 3.49 8,382.96 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 8:34:54AM Page 6 COMPASS 5000.1 Build 74 • 1110 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-146 Project: Kuparuk River Unit TVD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Site: Kuparuk 1D Pad MD Reference: Rig:67.1 +39.43 @ 106.53usft(Doyon 25) Well: 1D-146 North Reference: True Wellbore: 1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146 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) ("/100') (ft) Survey Tool Name 15,095.57 91.07 174.74 3,795.10 3,688.57 -5,628.94 6,362.68 5,953,528.16 1,707,109.87 2.95 8,456.09 MWD+IFR-AK-CAZ-SC(4) 15,185.08 90.45 174.94 3,793.91 3,687.38 -5,718.08 6,370.73 5,953,439.09 1,707,118.63 0.73 8,526.77 MWD+IFR-AK-CAZ-SC(4) 15,233.18 90.62 176.67 3,793.46 3,686.93 -5,766.05 6,374.25 5,953,391.16 1,707,122.54 3.61 8,564.25 MWD+IFR-AK-CAZ-SC(4) 15,278.40 90.59 177.87 3,792.98 3,686.45 -5,811.21 6,376.40 5,953,346.02 1,707,125.05 2.65 8,598.75 MWD+IFR-AK-CAZ-SC(4) 15,322.73 90.83 178.70 3,792.43 3,685.90 -5,855.52 6,377.73 5,953,301.73 1,707,126.73 1.95 8,632.06 MWD+IFR-AK-CAZ-SC(4) 15,371.45 90.79 180.27 3,791.75 3,685.22 -5,904.23 6,378.17 5,953,253.03 1,707,127.56 3.22 8,667.98 MWD+IFR-AK-CAZ-SC(4) 15,464.30 90.31 179.48 3,790.85 3,684.32 -5,997.07 6,378.37 5,953,160.20 1,707,128.51 1.00 8,736.02 MWD+IFR-AK-CAZ-SC(4) 15,556.99 90.11 178.39 3,790.51 3,683.98 -6,089.75 6,380.09 5,953,067.55 1,707,130.98 1.20 8,804.97 MWD+IFR-AK-CAZ-SC(4) 15,649.47 90.83 177.74 3,789.76 3,683.23 -6,182.17 6,383.22 5,952,975.16 1,707,134.84 1.05 8,874.70 MWD+IFR-AK-CAZ-SC(4) 15,740.60 91.14 177.16 3,788.19 3,681.66 -6,273.20 6,387.27 5,952,884.18 1,707,139.62 0.72 8,944.03 MWD+IFR-AK-CAZ-SC(4) 15,832.70 90.24 178.00 3,787.08 3,680.55 -6,365.20 6,391.16 5,952,792.22 1,707,144.25 1.34 9,013.98 MWD+IFR-AK-CAZ-SC(4) 15,923.64 89.22 177.84 3,787.51 3,680.98 -6,456.08 6,394.46 5,952,701.38 1,707,148.28 1.14 9,082.69 MWD+IFR-AK-CAZ-SC(4) 16,015.37 88.43 176.14 3,789.39 3,682.86 -6,547.66 6,399.28 5,952,609.85 1,707,153.83 2.04 9,152.95 MWD+IFR-AK-CAZ-SC(4) 16,108.82 88.67 175.65 3,791.76 3,685.23 -6,640.84 6,405.96 5,952,516.73 1,707,161.26 0.58 9,225.66 MWD+IFR-AK-CAZ-SC(4) 16,200.40 88.43 175.66 3,794.07 3,687.54 -6,732.13 6,412.90 5,952,425.51 1,707,168.93 0.26 9,297.15 MWD+IFR-AK-CAZ-SC(4) 16,292.91 90.62 178.19 3,794.84 3,688.31 -6,824.49 6,417.86 5,952,333.20 1,707,174.63 3.62 9,368.09 MWD+IFR-AK-CAZ-SC(4) 16,385.49 90.62 179.07 3,793.84 3,687.31 -6,917.04 6,420.07 5,952,240.69 1,707,177.59 0.95 9,437.28 MWD+IFR-AK-CAZ-SC(4) 16,412.21 90.66 178.12 3,793.54 3,687.01 -6,943.75 6,420.73 5,952,213.98 1,707,178.46 3.56 9,457.26 MWD+IFR-AK-CAZ-SC(4) 16,462.00 90.66 178.12 3,792.97 3,686.44 -6,993.51 6,422.36 5,952,164.24 1,707,180.49 0.00 9,494.77 PIOTrlMod Some 4 1/2"x 6-3/4" 16,472.00 90.66 178.12 3,792.85 3,686.32 -7,003.50 6,422.69 5,952,154.25 1,707,180.90 0.00 9,502.30 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and'or well position objectives have been achieved. [j Yes D No I have checked to the best of my ability that the following data is correct: D Surface Coordinates Q Declination & Convergence ( GRS Survey Corrections D Survey Tool Codes Dgitallys by Ya oars DN.v-vnc<nt Otsxa. Vincent Osara o.swaltmyar,a.saN�laa«yw. -rusxsesw om,c-us SLB DE: Dath 2015.07.111D23119-a'ro Pral Kota Kliort1 Client Representative: Kelsey HaIIford as l,. p/.m-RalrarHalaaM.a.Onaflg IWafts.w-CKA Wlam Y'ese Date f-VS iHte 2D15D776127M3-0BVO Date: 15-Jul-2015 7/15/2015 8:34:54AM Page 7 COMPASS 5000.1 Build 74 11111 Pro 2/4 - 139 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday,June 09, 2015 11:02 AM To: 'Hallford, Kelsey' Subject West Sak Well 1D-146( PTD 214-139) BOP Stack Kelsey, This BOP stack configuration is approved for West Sak Well(1D-146). Please include this approval with the approved PTD. 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.LoeopCcilalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp 01(907)793-1247 or Victoria.Loeoo@olaska.gov From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocoohillips.com] Sent: Monday, June 01, 2015 11:44 AM To: Loepp, Victoria T(DOA) Subject: PTD 214-139 BOP Stack Good morning Victoria, I wanted to share with you our BOP stack configuration for our upcoming West Sak well (1D-146) based on our maximum anticipated surface pressure of 1470 psi; 1897 psi downhole. Please let me know if you have any questions or concerns. Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallfordCct�,cop.com 1 OF T • • t.„1.).-ti s THE STATE Alaska Oil and Gas 4.40 tfA T A 1A.. ®I1SerVa1®11 Commission s _ 333 West Seventh Avenue - Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-146 ConocoPhillips Alaska, Inc. Permit No: 214-139 revised Surface Location: 312.3' FNL, 419' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 2047' FNL, 4271.4' FEL, SEC. 30, T11N, R11E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated October 28, 2014. 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, Daniel T. Seamount, Jr. Commissioner DATED this/U day of April, 2015. RECEIVED STATE OF ALASKA ' A OIL AND GAS CONSERVATION C JIDON APR 0 7 2015 PERMIT TO DRILL 20 AAC 25.005 vJ (/15�� ' ����/� OGCC la.Type of Work: 1 b. Proposed Well Class: Development-Oil ❑., . Service- Winj ❑ Single Zone Q , lc.Specify if well is proposed for: Drill 0% Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates 0 Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc . Bond No. 59-52-180 ` i.4.of D-146 • 3.Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 16472' • TVD: 3792' - Kuparuk River Field, 4a. Location of Well(Governmental Section): 7. Property Designation(Lease NurpJr): Surface: 312.3'FNL 419'FEL,Sec.23 Twn 11N Rng 10 E,UM • ADL 25650,28248 J , -/3 West Sak Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3865.4'FNL 1099.6'FEL,Sec. 13 Twn 11N Rng 10E,UM ' ALK 468,591 06/20/2015 Total Depth: 9.Acres in Property: r7/6 14. Distance to Nearest Property: 2047'FNL 4271.4'FEL,Sec.30 Twn 11N Rng 11E,UM (p '9 i -25560_ 5375 ft 4b. Location of Well(State Base Plane Coordinates-NAD7): 10. KB Elevation above I .106.6 feet 15.Distance to Nearest Well Open Surface: x-560670.7 y-444#046r23- ri. Zone-4 • GL Elevation above I , 67.1 feet to Same Pool: g0 ft 5/593541.3 16. Deviated wells: Kickoff depth: + 328 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: + 90.95 degrees Downhole: 1897 psi . Surface: 1470 psi . 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# H40 Welded 80' 39.5' 39.5' 119.5' 119.5' 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 3019' 39.5' 39.5' 3019' 2516' 1353sx Lead,205sx Tail DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7812' 39.5' 39.5' 7812' 3844' 920 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 8860' 7612' 3834' 16472' 3792' Slotted Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot Shallow Hazard Analysis❑ Diverter Sketch ElSeabed Report ❑ Drilling Fluid Program [./ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date April 2,2015 22. I hereby certify that the foregoing is true and correct. Kelsey Halford 265-1 Contact kelsev.hallfordna cop.com Email Printed Name G.Alvord Title Alaska Drilling Manager SignatureAc Phone 265-6120 Date �F(I+(Z.�3, Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 2J4-Met reviteal. 50-029-23527- OG-00 Date: \e,/41„10 2.0t4 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: Other: oi,/J tis f f-U 3 r5-0 U p5-iSamplesreq'd: Yes❑ No 2 Mud log req' d:Yes❑ No f}✓i -n /G2 r pre'VLA7 ' tz .5 7 1-6 Z 5-U o r25, H2S measures: Yes 2 N00Directional svy req'd:Yes 'No❑ Spacing exception req'd: Yes❑ Nog Inclination-only svy req'd:Yes 0 No[/ Aiv/ ,,... APPROVED BY Approved b . V// GJ / COMMISSIONER THE COMMISSION Date: v[L 4/ ` !,5� ,a e/<46 1/7iI3 Submit Form and Form 10-401(Revised 10 2012) T r ii>�ikOlill ti w�'�'rtS from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate 'bnl- 11•Pv RECEIVE® ConocoPh l l lips AP R 072015 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 Kelsey Hallford Phone (907) 265-1577 April 2, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Revised Application for Permit to Drill (PTD 214-139), West Sak Producer, 1D-146 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby Revises the Permit to Drill 1D-146 (214-139) due to recent results seen while drilling 1D-142 (214-149). After setting surface casing on 1D-142 and drilling out our shoe track to do our LOT, ConocoPhillips struggled to get a good LOT due to the location of our surface casing shoe. Due to the difficultly experienced to get a good LOT, ConocoPhillips revises our permit to drill for 1D-146 to set deeper surface casing to hopefully prevent similar results for 1D-146 surface casing LOT. Setting deeper surface casing also adjusted our directional plan. Please find attached for the review of the Commission, form 10-401 and the information required by 20 ACC 25.005 for the wellbore of 1D-146 (214-139). Sincerely, i 'el()A16Ca4P-1—c'( Kelsey Hallford West Sak Drilling Engineer • application for Permit to Drill,Well 1D-146 Revision No.0 Saved:2-Apr-15 Permit It - West Sak Well #1 D-146 66 r., Application for Permit to Drill Document MaMell M p x i rrli a $ Well Volae Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005 (c)(11) 6 1D-146 PERMIT_WP07.doc Page 1 of 7 Printed:2-Apr-15 • application for Permit to Drill,Well 1D-146 Revision No.0 Saved:2-Apr-15 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005 (c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CemCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005(t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-146. 2. 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 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 312.3' FNL 419'FEL, Sec. 23 Twn 11N Rng 10 E, UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 106.6'AMSL Northings 5,959,353.8 Eastings:560,670.7 Pad Elevation 67.1'AMSL Location at Top of 3865.4' FNL 1099.6' FEL, Sec. 13 Twn 11N Rng 10E, UM Productive Interval (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7193' Northings: 5,961,119 Eastings:565,254.2 Total Vertical Depth, RKB: 3806' Total Vertical Depth, SS: 3699' Location at Total Depth 2047' FNL 4271.4' FEL Sec. 30 Twn 11N Rng 11E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 16472' Northings: 5,952,394.5 Eastings: 567,139.8 Total Vertical Depth, RKB: 3792' Total Vertical Depth, 5S: 3685' 10-146 PERMIT_WP07.doc Page 2 of 7 Printed:2-Apr-15 • •application for Permit to Drill,Well 1 D-146 Revision No.0 Saved:2-Apr-15 and (D)other information required by 20 MC 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 1: Directional Plan 1D-146 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. 3. 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 MC 25.035,20 MC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stick will be utilized to drill and complete well 1D-146. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. 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 expected reservoir pressures in the West Sak sands in the 1D area are 0.489 psi/ft, or 9.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,470 psi, calculated thusly: MPSP = (3878 ft TVD)(0.489 - 0.11 psi/ft) = 1,470 psi (B)data on potential gas zones; The well bore is not expected to penetrate any 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; Please see Attachment 2: 1D-146 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests 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 MC 25.0300; 1D-146 PERMIT_WP07.doc Page 3 of 7 Printed:2-Apr-15 . opplication for Permit to Drill,Well 1D-146 Revision No.0 Saved:2-Apr-15 1D-146 will be completed with a 7-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. 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 Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H40 Welded 80 39.5/ 39.5 119.5/ 119.5 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 10.75 13.5 45.5 L-80 Hydril 563 3019 39.5 / 39.5 3019/ 2516 1344 sx DeepCrete Lead, 195 sx DeepCRETE Tail Cement Top planned @ 4800' 7.625 9.875 29.7 L-80 Hydril 563 7812 39.5 / 39.5 7812/ 3844 MD/3154'TVD Cemented w/ 920 sx 15.8 ppg Class G' 4.5 6.75 11.6 L-80 Hydril 563 8860 7612/ 3834 16472 / 3792 slotted—no cement slotted 6. 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); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-146 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 1D-146 PERMIT_WP07.doc Page 4 of 7 Printed:2-Apr-15 • 4IApplication for Permit to Drill,Well 1D-146 Revision No.0 Saved:2-Apr-15 7. 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/n the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 — 9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8— 11.2 Lateral Mud Program (MI FazePro OBM) Intermediate Hole Mud Program (LSND) Value Density(ppg) 9.6 Fann 35 6 RPM 10.75"Csg Shoe to 7-5/8"Csg Point (lb/100 ft2) 4 -8 Value HTHP Fluid Loss Density(ppg) 9.2 - 9.6 (mL/30min) <5 Fann 35 6 RPM 12 - 16 Drill Solids <5% (Ib/100 ftp) API Filtrate Oil Water Ratio 70:30 (cc/30 min) <6 Electrical >400 pH 9.5 — 10.0 Stability(mV) Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) 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: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) 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: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1D-146 PERMITWP07.doc Page 5 of 7 Printed:2-Apr-15 aapplication for Permit to Drill,Well 1 D-146 Revision No.0 Saved:2-Apr-15 10.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) 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: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) 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: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.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 also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16"x 24"insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 25. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13.5" hole to casing point at +/- 3019'MD/ 2516'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10.75", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 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 9.875" bit and 6.75"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 12.0ppg EMW, recording results. 8. Directionally drill to 7-5/8"casing point at 7812' MD/ 3844'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 7.625", 29.7# L80, Hydril 563 casing to surface. (top of cement to be 4800' MD/ 3154'TVD which corresponds to 500'above the Ugnu B formation). 11. Install wellhead x 7.625" packoff and test to 3500 psi. 12. Flush 10.75"x 7.625"annulus with water, followed by diesel. 13. PU 6.75" PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 14. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 12.0ppg EMW, recording results. 15. Directionally drill 6.75" hole to West Sak D Sand to TD at +/- 16472' MD/ 3792'TVD as per directional plan. 1D-146 PERMITWP07.doc Page 6 of 7 Printed:2-Apr-15 `Application for Permit to Drill,Well 1D-146 Revision No.0 Saved:2-Apr-15 16. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 17. PU and run 4-1/2"slotted liner. 18. Set liner hanger @ +/- 7612' MD/ 3834'TVD, set liner top packer. POOH. 19. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 20. Nipple down BOPE, nipple up tree and test. Pull BPV. 21. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 22. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) 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: (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.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1D-146 PERMIT_WP07.doc Page 7 of 7 Printed:2-Apr-15 9..35,Apr:'..02 2015 i S 1 D-1 46wp07 7 '207 Plan Summary - t3 k15 Top W Sak --_� "- .•- a - _ c n r ugb `` N o • - Base Permafrost -1--1 ,--I- ✓ 1\���� I�i�� 0 r i 1i I-1 I i I 0 0 I 4000 8000 12000 16000 \� �, 10 3/4"x 13-1/1 Measured Depth :Tjo;1:1: ile, lit iii •ro 0 o0o I7-5/8"x 9-7/81 14 1/2"x 6-3/4"1 M r`m o I o co 0o I --. , I CO m m m I -- I I I 1 I I I I I I .!...1 131 IrI dl '¢Y._.._.I I _..EAI --. •--..,.._ g� 40 - 328 0 1500 3000 4500 6000 751) 9000 °105?0 (2000' 13580' 15000 0 328 - 510 Horizontal Departure 510 - 690 390 . .>r��Irom�ame seen ek cneon wPou ' - 1 • •�•` / 690 - 870 a 43L3wp15 __..... 111111111111111111' - .. __ :: e:(:• .e6(p2/27/o6) r, oIP� , i'' 10870 - 1060 60 - 1240 N 60 I ►. 300 4.';. �r4 r..i r e "sem 1240 - 1420 Q ..\ .. ..... . .iins. ♦ 1420 - 1600 miill ` c 1D 143L1wp15III r,Ir+ < ' (n \�.\ .._.. ._ 0 - 2230 ♦A d ; ®3 2230 2850 d ' \._.,�1(D.143wp15 1.x..142.. ._ ':. 1e1i '�'4' �c lir v. -p IM MO] 30 , �\ �\ �1.et.,` I\• ,i Ic. Ir1 •• :• ( t 2850 - 3480 0 1 \ ..i°` 270 ♦ :d� • k I 3480 - 4100 ‘1,11)-30`I d ._ , 10-142w.r coil,' AI' •�nu`•Si .... .._ .,." SP .10,;, O 90 4100 - 4730 1�-28L1 %, i;. lei%' ®�,,:..1 4730 - 5350 U 1D_-30 /•" r �� �Si�r it,:n/"// 5350 5980 0 ,. q• 14' ��r, a ��05980 - 6600 r a�0 6600 - 7830 0 2500 5000 7500 10000 12500 15000 240 + s�'l= 7830 - 9070 SURVEY PROGRAM , 10 9070 - 10300 Surface Location v , k ;, /�1„(� I '' 10300 - 11540 Iepth From Depth To Survey/Plan Tool ft, ; 39.50 1700.00 1D-146wp07(Plan:1D-146) GYD-GC-SS Pad Elevation:67.10 210 •.L'• 11540 - 12770 1700.00 2700.00 1D-146wp07(Plan:1D-146) MWD 12770 14000 1700.00 3019.11 1D-146wp07(Plan:1D-146) MWD+IFR-AK-CAZ-SC 180 14000 - 15240 3019.11 4519.11 1D-146wp07(Plan:1D-146) MWD CASING DETAILS 15240 - 16472 3019.11 7811.66 1D-146wp07(Plan:1D-146) MWD+IFR-AK-CAZ-SC TVD MD Name M 7811.66 9311.66 1D-146wp07(Plan:1D-146) MWD 2515.60 3019.11 10 3/4"x 13-1/2 Magnetic Model: BGGM2014 T 7811.66 16471.69 1D-146wp07(Plan:1D-146) MWD+IFR-AK-CAZ-SC 3843.60 7811.66 7-5/8"x9-7/8" Magnetic Model Date: 22-Jul-15 3791.60 16471.69 41/2"x 6-3/4" Magnetic Declination: 18.84° To convert a Magnetic Direction to a True Direction,Add 18.84°East SECTION DETAILS - 1662.6 Sec MD Inc Azi TVD +N/-S +FJ-W Dleg TFace VSect Target Annotation Base Permafrost 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 328.00 0.00 0.00 328.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.11100'DLS,110°TF,for 379.9' -1873.6 3 707.90 4.18 110.00 707.56 -4.74 13.01 1.10 110.00 12.34 Start 2.51100'DLS,-4°TF,for 500' 4 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 Start 2.61100'DLS,-55°TF,for 443.02' t3 5 1650.92 25.05 84.30 1612.60 -41.30 253.68 2.60 -55.00 203.22 Hold for 110.38' 6 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 Start 4.361100'DLS,-41.54°TF,for 1118.29' -2128.6 7 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 Hold for 1590.86' 8 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 56226 Start 1.731100'DLS,90.98°TF,for 1911.78' 9 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 Start 4.65/100'DLS,32.67°TF,for 295.52' 10 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 Hold for 45.36' 11 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 Start 4.65°/100'DLS,87.4°TF,for 1088.55' 12 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1D-146 15May14 T1 MW Hold for 20' 13 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 Start 2/100'DLS,73.97°TF,for 103.64' 14 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 Hold for 980.88' 15 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 Start 2.5°/100'DLS,83.02°TF,for 463.34' k15 16 9379.51 90.00 158.49 3877.60 -5.48 5876.86 2.50 83.02 4012.02 1D-146 15May14 T2 MW Adjust TF to-80.39°,for 114.18' 17 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 Hold for 528.45' 18 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 Start 2.5/100'DLS,87.76°TF,for 493.32' 19 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 1D-146 15May14 T3 MW Adjust TF to 89.89°,for 415.07' 20 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 Hold for 397.99' 21 11328.51 90.95 178.38 3853.16 -186924 6352.87 0.00 0.00 5699.73 Start 2.5°/100'DLS,105.46°TF,for 39.32' 22 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW Hold for 5103.85' 23 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW TD:16471.69'MD,3791.6'TVD -3146.6 ugc -3353.6 ugb -3486.6 a -358'59.6 N 386lop E6W Sak ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified othervrse,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie • o a 0 Northing 0500 usft/in) iiiiIm iIiiiiIiiiiIiiilIiiiiIiiiIIIIIiiiiIiiiiIiiiiIi , i , Imil m iIii a 0 0 U l5 ,rO N 3 a cn a) co as S 0 N E N 3 V ct oO 0 0m cc r rr . a N N. 0 N . 1- 0 0 00 O N N 0 _ �J T CO 9T J ! •CM { In .c...1.— .. i O- p N a 1 I' M yr • f0 A N i� ', mm O 1 r0 =,) N _ i 0T Ago,.1' N ,.�. .. T ,- 0 • O Ill 77 w A,_. -,.M; _ 117 P :' TN CJT" ' : i4CO— yt t1:5 1 �► U J ,„ Jr :: a w 3 I III 43 A., L.,, ::,,.__ .: ,,i, ... 'IN 4. i . IP 110-. .4(110_,r'l, :,\: 4,-': ,,a3 ,.-M 7 ; lir ;., t... .a_ •_ MVP P "r"." I:,),45, 0.:4 7W1--4 lici 1 " -•• ,.i;*.4. -; _LT: • eL • -'''" A 00.± .1j.'. ; D ,i!, d'illWIMVIIII''•-•-• -c'17) ° N,ci (Lf". irAllF. P.' li --::- :'''.' . 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CO CO CO r O V CO r M r M N 0f) V) N- in in V LO CD in M N O O N CO 0 N in Cr CO CO (O V M V co V co („) ` r N r M r co O co Co O V O CO 01 N N CO CA V V N CO V V V V V 'Cr O 0 M N CO 'Cr 4 V in n) n) V M 6 6 N to N N r r r M N E ti r r r r r r r r r r r r r ,- co co co N 1,- 0 0 0 0 0 0 0 0 00000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0000 0 0 0 0 0 0 12 o ui Lai ui ini cci 0 0 0 0 0 (ri o in o i(i o o (ri o in vi in o cci 0 cci 0 O L N N N- N 1` N N Cn Ln Cn O N- O N O N- O )O N iO N I- N (O N (n N (O y ' = O CO CA CO CP r r r Or CP O CD O W O CO. _ _ V (D _ _ _ _ _ _ (� y• y r r O O O r r r r r r r r r r r r r m 8 2 p� V co O 6) N I� V 0 0 CA 4 r 0 V r N CD N r CO r N CO CO r CO C 6) V O CO O CO CA 00 CO CD CO (O (O CO I- CO 'Cr (A N CA N N N N O CO N O O M N N 'n vi M ni M M M M 'A 6 6 O 6i CO O] W CO OJ 600 00 O 0 0 0 N W M N N M M M co co M N N c- 0,y a` = r r N N N N NN NDIDINNN co Q N CO O 0 CO N N 0) N- N N N CO N CO LO CO CO CO CO 0 Cl.. 0 V0 Cr 0 Cr 0 Cr 0 O 'p V in CO C7) CO N- M n M (O O M N M N O CO M CO M CO M 1.. 2 r O N N (") ("i M M M I- 6 Ci I- N (O N ci M M O r CO C"] m M CI(1 M W 4) • = N N CO M N M 000 in O O O W O W O M M (n M CO M Cn M Cn M Cn O) • ' CA O CO CA CO CA O O 0 O r CA O CD O W O 00 V CD 16 r r r r r r ,- r r r r r r r d r r r LL- N V E C CD CO 0 CO CD M 6) N O N- co cr ,- ,- O V LO CO Cn CO N CO T- I,-CO 0 V CO N- CO O � O N- O N CO N 6 6 6 CO N CO CO M Ma; 6) 6) 0] 6) 6) Ma) I- CO O M r CO I- M N- y E U `c-s1 `c:1 r r r r n) O) (A V V N V V V V .<5:i CO N N CO M N N N CO CO N • C �' N N N N N N CO N N N N N N C E .2 N O C y 2 O m 2 0 a coa u) O co V N CA N- N N N in CO LO in in CO in CO 0 V O Cr 0 Cr 0 V' 0 V 0 (p 0_ o 10 N V (n CO 6) CO - r r r (O - r CD r (fl r CO (O N M N CD (O CO N CO CC) M • C Nd d = f� O N CO M M M M M N- n M N- N O N O M M W I- O M O M W M CO rC a0w V NO 2 M) OM) O O O O0 W) O in O N O M MiM NMiMnMi o 7 r r r r r r r r r rd r d 4 r r rQwVN E r C 6 E 3 = CO o tOm I' z E m 6 t m = a ❑ C y T co T i a .0 O 01 C (j Cr y U N N Cn Cn Cn Lo N CU C 0 a a a n. a n. d 6 v CD 3 3 3 3 3 3 L U N O (O (n N N M M (o E O. J J J J J J o C 7 (y CO 3 O- CZ CO CO CO CO CO CO 0 _ 1y6 d z v v v c V vOC d. d 0 N 0 co M CO M r r r r r N- W W m 'td• ❑ ❑ ❑ ❑ ❑ ❑yO L Q LL K ❑LR • a ❑ ❑ ❑ ❑(6 coR N Itiiii d CO 32 O U N p ' 0 a Y a Y J J VV M M M M MJ J M M JM MJ C1O0_ QQ Q NN ❑ e, VV V V V V V V V V V CD EY O 00 V mm VV re n7 E n m O O 1' .,- ❑ ❑ N N N N ' ' ' ' r 6 6 6 6 ❑ ❑ ❑ ❑ ❑ ❑ (n (7MMV 'q ❑ ❑ Vr7VVVV ❑ ❑ rrrrrrrrrrap6 C 4. 7 , N —2 ❑ ❑ ❑ ❑ ❑ mN ❑ ❑ 0 ' ' a s W C •C C co N O . O ,..i V m ' n amcomm mmmcamw ' Q Q , 0_ d ' ' , LL a LL LL d d IL d d d 0. • tC 0 aa.., A 6) 0 0 0 0 N CO NN CO CO CO CO QC Vw Z Cr) C7s- C C') MV' 1- 1- V' V' I VY Y r 't 't Vi 'r 1 y. co' co' M co' M co' M co' co' co' Q y o y CN ❑ ❑ ❑ ❑ ❑ ❑ 00000 ❑ ❑ ❑ ❑ ❑ ❑ rVVV V V V VVV V - N o � corrrrrr , Oo _ c , , , , 1 , , 06666 666666 () C y C a Z 0. 0) 6) O O O O NN NNNNNN MMVVVVVVVVVVVVVVVC Q. i▪'+ s-...• O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0) 7 0 m K dn 0 r r r r r r r r r r r r r r r r r KK KKK KKKKKK Y _ ; d C C i N01 01 U U F re co co • 0 =1. 1 \ 2 ƒ ) 'E 0 / / ,-- £ ( - ) } Cl) $ es \ \� Clo ) ) \ ) 0 \ E / /\ al c S / j E s { y 2 0 § ) > < < < O 2 [ } } } N- La Q / s S » a E. ` 4 0a / = \ a } / � ( RRRR4R o > > » > > al LO ) k©a 4. � - 2 e � /U \ ) oa o co CO Vit® k - 2 / ia } 2 = / E « » 0 Ee | _ CU \ w _ ' © - CI as 2 ^ � s o.at 3 CO _co N- w N- N- N- N- N- 0 - s } \ _ 0 � Se / \ / / \ / } $ / I ) � 2 • % � 3 ,- . 33 . 3 / _ J § £ 6663666 = ® I § & e t ! CO / ) \ \ j _ , § - § k { I ] E j F \ ) \ \ \ \ ' \ 0 ( 6 ƒ w az ¥ < a \ : a) § _ § m J / \ / / ƒ t / } o ' \ \ _ ` E E _ , = ® ® ` 2 { 0) k c / \ \ \ § ® n ) \ \ \ \ \ , 2f ! ) # % Q o j § % ) 7 j % � � � � rraw CUto a) co - - • 2 — m \ « \ a E - _ , re .7( } w \ \ \ \ % } \_ \ \ \ } \ 0 tKQ & k G ® ` / k } � Q 3 2 r \ § - ) 3 6 ° ! csj _ \ ) L ° @ ° C � ) ( - J [ a G o 2 - . ,- m ; @ 2 2 k - ) ) ) ) / \ \ j \ \ 1 D-1 46w 07 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a N 7- 0 o .fir a ®n� m o E m Sto 7 N .Ea /'.ili%V.-Vi;YA A.OAA,'. , 0 0 0 300-. _ 1' I i I o fI 'W + I ¢1 / 11 I 111 I1,II sirj : Q 1 ! , ij � o •; 150- 11 NL_ o' 1 , - o - Mmpplllllp; �.�' 1, � II c - IIIIIIIIIIIII6 p VIII / .._. .. ..._ 0) mll11 -_Equiveiant Magnetic Distance - ,lllll10II' 0 1 1 1 1 I 1 I I I I 1 I I I I I I I I I I I I 1 I I I 1 I I 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire wellVeasured Depth 39.50 To 16471.69 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 39.50 To 16471.69 Results Limited By: Centre Distance: 1843.22 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1700.00 1D-146wp07 (Plan: 1D-146) GYD-GC-SS 1700.00 2700.00 1D-146wp07 (Plan: 1D-146) MWD 1700.00 3019.11 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 3019.11 4519.11 1D-146wp07 (Plan: 1D-146) MWD 3019.11 7811.66 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 7811.66 9311.66 1D-146wp07 (Plan: 1D-146) MWD 7811.66 16471.69 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2515.60 3019.11 10 3/4" x 13-1/2 10-3/4 a 10-1. 3843,60 7811.66 7-5/8"x 9-7/8" 7-5/8 -41,113 3791.60 16471.69 4 1/2"x6-3/4" 4-1/2 Doyon 1 Doyon 1 Doyon 141,1J-122 L2,1J-122 L2(wp08)VO -E}- 1 D-129,1D-129,10-129 V2 - 1D-37,1D-37,1D-37 V4 1C-13(,1C-135 V2 -0- 10-130,1D-130,10-130 V2 -1-- 10-37,1D-37L1,1D-37L1 V1 1C-139PB1,1C-135PB1 V17 -A- 10-131,10-131,10-131 V2 -At- 1D-37,1D-37L2,1D-37L2 V3 1C-18,,1C-184 Vo -1- 1D-132,1D-132,1D-132 V2 -0- 1D37,1D-37L2PB1,1D-37L2PB1 V1 1C-19(,1 C-190 VO -8- 1D-133,1D-133,1D-133 V2 -I- 1D-38,1D-38,1D-38 V2 ID-O5, 0-05 V6 -e- 1D-133,1D-133PB1,1D-133PB1 V2 -1- 1D-39,1D-39,1D-39 V2 ID-06, 0-06 V6 -A- 1D-134,1D-134,1D-134 V2 -X- 10-40,1D-40,1D-40 V4 I D-07, D-07 V3 --0-- 10-135,10-135,1 D-135 V2 --0-- 10-40,1 D-40A,1 D-40A V1 ID-09, 0-09 V5 -I- 10-141,10-141,10-141 V2 - 10-41,1D-41,1D-41 V1 ID-10, D-10 V2 -A- 10-141,1D-141A,1D-141A VO -e- 10-41,1D-41PB1,1D-41PB1 V4 ID-11, 0-11 V2 -8- 10-141,1D-141APB1,1D-141APB1 VO -9- 10-41,1D-41PB2,1D-41PB2 V1 ID-1112,1D-11L1 V1 -e- 1D-141,1D-141APB2,1D-141APB2 VO --e- 10-42,1D-42,1D-42 V2 ID-11LE,1D-11L2 V5 -0- 1D-141,1D-141APB3,1D-141APB3 VO -0-- 1D-42,10-42,1D-42(Baker)V1 1D-111,1PB1,1D-11L2PB1 V1 -A- 10-141,1D-141L1,1D-141L1 V2 -A- 1D-42,1D-42L1,1D-42L1 V1 10-111,1D-117 V2 -X- 1D-141,1D-141L1PB1,1D-141L1PB1 V2 -X- 1D-42,1D-42L1PB1,1D-42L1PB1 V1 1D-11£,10-119 V2 -I- 1D-141,1D-141L1PB2,1D-141L1PB2 V2 -0- Plan:1D-143,Plan:1D-143,1D-143wp15 V0 ID-12, D-12 V9 -B- 1D-141,1D-141PB1,1D-141PB1 V2 -9- Plan:1D-143,Plan:1D-143L1,1D-143L1wp15VO ID-12L',1D-12L1 VO -0- 1D-28,1D-28,1D-28 V4 -e- Plan:1D-143,Plan:1D-143L2,1D-143L2wp15 VO ID-12L PB1,1D-12L1PB1 VO -e- 1D-28,1D-28L1,1D-28L1 V8 -9- Plan:10-143,Plan:1D-143L3,1D-143L3wp15 VO ID-12L(,1D-12L2 VO -e- 1D-30,1D-30,1D-30 V6 -x- Plan:1D-145,Plan:1D-145,1 D-145wp09 VO 1D-120,1D-120 V2 -0- 1D30,1D30L1,1D-30L1 V2 -e- Rig:1D-142,10-142,1D-142 VO 10-121,1D-121 V2 -X- 1D-32,1D-32,1D-32 V5 -e-- Rig:1D-142,10-142,1 D-142wp07 VO I I 1. 1 D-1 46w 07 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. N m I a W E A.: ;,-,1a n m mNe1 4 5. E OdmOO ,_ - d 'i', 11 ,, Ali I I�14Ib I I lit lII " ,_ ' i I 300 ; 9 1 11, �� o iltl �y' � I III _ ;1,1:' lll� I I i il' p Ikld ..�I.,,,,,„„11,11111,1, .. YI i��l IN �IpAlP I Ili 1YVIItlNk, 0 ll. M u cn °` .1111',, lit 1 a1 1I� �'; Y150-_ - IIiIV II Illj iII �I�' o - r �i y ® III y 1 0 \i "..; I I I I I I 1 1 I 1 1 1 I I 1 1 I I 1 1 i 1 Equivelant Magnetic Distance 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.50 To 16471.69 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 39.50 To 16471.69 Results Limited By: Centre Distance: 1843.22 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1700.00 1D-146wp07 (Plan: 1D-146) GYD-GC-SS 1700.00 2700.00 1D-146wp07 (Plan: 1D-146) MWD 1700.00 3019.11 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 3019.11 4519.11 1D-146wp07 (Plan: 1D-146) MWD 3019.11 7811.66 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 7811.66 9311.66 1D-146wp07 (Plan: 1D-146) MWD 7811.66 16471.69 1 D-146wp07 (Plan: 1 D-146) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 a ,D, 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 -41,1D 3791.60 16471.69 4 1/2"x 6-3/4" 4-1/2 Doyon Doyon Joyon 41,1J-122 L2,1J-122 L2(wp08)V0 -9-- 1D-129,1D-129,1D-129 V2 -0- 1D-36,1D-36L1,1D 36L1 V3 1C-13:,1C-135 V2 -8-- 1D-130,10-130,1D-130 V2 -e- 1D-36,1 D-36L2,1 D-36L2 V1 1C-13SPB1,1C-135PB1 V17 -A- 1D-131,10-131,1D-131 V2 -X- 1D37,1D-37,1D-37 V4 1C-18,,1C-184 VO -f- 1D-132,10-132,1D-132 V2 1D-37,1D-37L1,1D-37L1 V1 1C-190,1C-190 VO $ 1D-133,1D-133,1D-133 V2 -A- 10-37,1D-37L2,10-37L2 V3 ID-05, D-05 V6 $ 1D-133,1D-133P81,1D-133P81 V2 -0- 1D37,1D-37L2PB1,1D-37L2PB1 V1 10-06, D-06 V6 -X- 1D-134,10-134,1D-134 V2 - 1D-38,1D-38,1D-38 V2 ID-07, D-07 V3 -e- 1D-135,1D-135,1D-135 V2 - - 1D-39,1D-39,1D-39 V2 ID-09, D-09 V5 -I- 1D-141,10-141,10-141 V2 --0- 1D-40,1D-40,1D-40 V4 ID-10, D-10 V2 -A- 1D-141,1D-141A,1D-141A VO -9-- 1D-40,1D-40A,1D-40A V1 ID-11, D-11 V2 $ 1D-141,1D-141APB1,1D-141APB1 VO -kr- 1D-41,1D-41,1D-41 V1 ID-11L,1D-11L1 V1 -e- 1D-141,1D-141APB2,1D-141APB2 VO -8- 1D-41,1D-41PB1,1D-41PB1 V4 ID-11LE,1D-11L2 V5 -El- 1D-141,1D-141APB3,1D-141APB3 VO -i- 1D-41,1D-41PB2,1D-41PB2 V1 ID-11L2PB1,1D-11L2PB1 V1 -A- 1D-141,1D-141L1,1D-141L1 V2 --8- 1D-42,10-42,1D-42 V2 1D-11i,10-117 V2 -X- 1D-141,1D-141L1PB1,1D-141L1PB1 V2 -e- 10-42,1D-42,1D-42(Baker)V1 1D-11E,1D-119 V2 - 1D-141,1D-141L1PB2,1D-141L1PB2 V2 - 1D-42,1D-42L1,1D-42L1 V1 ID-12, D-12 V9 -8- 1D-141,1D-141PB1,1D-141PB1 V2 $- 1D-42,1D-42L1PB1,1D-42L1PB1 V1 ID-12L,10-12L1 VO 10-142,10-142,10-142 VO -X-- Plan:1D-145,Plan:1D-145,1D-145wp09 VO ID-12L PB1,1D-12L1PB1 VO -8- 1D-142,1D-142,1D-142wp07 VO -e- Rig:10-143,Plan:1D-143,10-143 VO ID-12L2,10-12L2 VO -0- 1D-28,1D-28,1D-28 V4 -el- Rig:10-143,Plan:10-143,1 D-143wp15 VO 10-120,1D-120 V2 --9- 1D-28,1D-28L1,1D-28L1 V8 -X- Rig:10-143,Plan:1D-143L1,1D-143L1wp15 VO 1D-121,1D-121 V2 -9- 1D-30,1D-30,10-30 V6 $- Rig:10-143,Plan:1D-143L2,1 D-143L2wp15 VO • • Ladder View 1 D-146w 07 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. N n n m a. J M b J Z1 N O <QM 60 --.nIA I 1 �i I 1 I Iii al__ ..0 r 0 E.:, „oil 41 CL CD CO 0 J , r 15 30 - -..nIII1G111111111D..� AMIII!IIIIIIIIIIIjillllflll�► �, n1n1n,.. -1119 U _ Equivelant Magnetic Distance _J/ I I I I I I I I II I I I I I I I I .....I I I _....III I I... 0 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire well:Measured Depth 39.50 To 16471.69 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 39.50 To 16471.69 Results Limited By: Centre Distance: 1843.22 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1700.00 1D-146wp07 (Plan: 1D-146) GYD-GC-SS 1700.00 2700.00 1D-146wp07 (Plan: 1D-146) MWD 1700.00 3019.11 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 3019.11 4519.11 1 D-146wp07 (Plan: 1 D-146) MWD 3019.11 7811.66 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 7811.66 9311.66 1D-146wp07 (Plan: 1D-146) MWD 7811.66 16471.69 1D-146wp07 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 ,D-i' 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 -41,1D 3791.60 16471.69 4 1/2"x 6-3/4" 4-1/2 )oyon 1 )oyon 1 )oyon'41,1J-122 L2,1J-122 L2(wp08)VO -8- 1 D-129,1D-129,1 D-129 V2 --e- 1D-36,1 D-36L1,1 D-36L1 V3 1C-13(,1C-135 V2 -e- 1D-130,1D-130,10-130 V2 -e- 1D-36,1D-36L2,10-36L2 1/1 1C-139 PB1,1C-135PB1 V17 -A- 10-131,1D-131,1D-131 V2 -X- 1D-37,1D-37,1D-37 V4 1C-18',1C-184 VO -1- 1D-132,1D-132,10-132 V2 -X- 1D37,1D-37L1,1D-37L1 V1 1C-15,1C-190 VO $ 1D-133,1D-133,1D-133 V2 -g- 1D-37,1D-3712,1D-37L2 V3 ID-05, D-05 V6 -e- 1D-133,1D-133PB1,1D-133PB1 V2 -0- 1D37,1D-37L2PB1,1D-37L2PB1 V1 ID-06, D-06 V6 -X- 1D-134,10-134,1D-134 V2 1D-38,1D-38,1D-38 V2 ID-07, 0-07 V3 -e-- 10-135,1D-135,1D-135 V2 -I- 1D-39,1D-39,1D-39 V2 ID-09, D-09 V5 -1-- 1D-141,1D-141,1D-141 V2 -.8,- 1D-40,10-40,1D-40 V4 ID-10, D-10 V2 -A- 1D-141,1D-141A,1D-141A VO -e- 1D-40,1D-40A,1D-40A V1 ID-11, D-11 V2 -8- 10-141,1D-141APB1,1D-141APB1 VO -A- 1D-41,1D-41,1D-41 V1 ID-11L',1D-11L1 V1 -e- 10-141,1D-141APB2,1D-141APB2 VO -8- 1D-41,1D-41PB1,1D-41PB1 V4 ID-11U,1D-11L2 V5 --0-- 10-141,1D-141APB3,1D-141APB3 VO -)- 1D-41,1D-41PB2,1D-41PB2 V1 ID-11L9PB1,1D-11L2PB1 V1 -A- 1D-141,1D-141L1,1D-141L1 V2 $ 1D-42,1D-42,1D-42 V2 1D-117,10-117 V2 - 1D-141,1D-141L1PB1,1D-141L1PB1 V2 -e•- 1D-42,1D-42,1D-42(Baker)V1 1D-11£,1D-119 V2 -X- 1D-141,1D-141L1PB2,1D-141L1PB2 V2 -X- 1D-42,1D-42L1,1D-42L1 V1 ID-12, D-12 V9 $ 1D-141,1D-141PB1,1D-141PB1 V2 -0- 1D-42,1D-42L1PB1,1D-42L1P61 V1 ID-12L,1 D-12L1 VO -e-• 1D-142,1D-142,1D-142 VO - Plan:1D-145,Plan:10-145,1 D-145wp09 VO ID-12L PB1,1D-12L1PB1 VO -9- 1D-142,10-142,1D-142wp07 VO -e- Rig:10-143,Plan:1D-143,10-143 VO ID-1212,1D-12L2 VO -0- 1D-28,1D-28,1D-28 V4 -0- Rig-1D-143,Plan:10-143,1 D-143wp15 VO 10-120,10-120 V2 -e- 1D-28,1D-28L1,1D-28L1 V8 - Rig:1D-143,Plan:1D-143L1,1D-143L1wp15V0 10-121,1D-121 V2 -9- 1D-30,1D-30,1D-30 V6 -g- Rig:10-143,Plan:1D-143L2,1 D-143L2wp15 VO 0 MD Inc Azi TVD 4,1/-S ...E/-W Oleg T VSect Target IOU ..i1t1 39 50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 1D-146wp07 32800 0.00 0.00 328.00 0.00 0.00 0.00 0.00 0.00 328 510 707.90 4.18 110.00 707.56 -4.74 13.01 1.10 110.00 12.34 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 39.50 To 16471.69 1650.92 25.05 84.30 1612.60 -41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 690 870 1410,March 12 2015 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 562.26 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 870 1060 ----- 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1060 1240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1D-146 15May14 T1 MW 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 Moth From Depth To Sorvey/Plon Tool 39.50 10-146wp01(Plan:10-146) GY13-GCSS 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 1420 1700.00 1703.00 2703.00 113-146wp0)(Planz 10.146) MWO 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 1700.00 3019.11 113-146wp07(Plan:1.146) MW13.1FRAK-CAZ-SC 3291 9379.51 90.00 158.49 3877.60 -5A8 5876.86 2.50 83.02 4012.02 1D-146 15May14 T2 MW 1420 1600 4519.11 113-146wp07(Plan:1D-146) MWD 3019.11 7811.66 10-1460p0)(P4n:10-146) MW13.0143-AK-CAZ-SC 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7811.66 9311.66 1D-1460p37(Plan:1.146) MWO 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 1600 2230 7811.66 16471 69 113-146wp07 Mien:1D-146) MW11.1FR-AK-CAZ-SC 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 10-146 15May14 T3 MW 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW ND MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 TO MW 2850 3480 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/80 9-7/8" 7-5/8 3480 4100 3791.60 16471.69 4 1/2"x 6-3/4" 4-1/2 4100 4730 4730 5350 5350 -- 5980 0/360 5980 6600 6600 7830 ;le ig,;0, rya___ -- ,...",.::, :zip.,.) 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L1,nt1 W 111111-3 1111 B:;GIIIra, lbMD Inc Azi TVD +N/-S +E/-W Dleg T� VSect Target 4U 311$ 39.50 000 0.00 39.50 0.00 0.00 0.00 0.00 1 D-146Wp07 328.00 0.00 0.00 328.00 707.90 4.18 110.00 707.560.00 -4.74 0.00 0.00 0.0 13.01 1.10 110.00 0.00 12.34 328 510 1000.00 To 2000.00 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 1650.92 25.05 84.30 1612.60 41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 690 870 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 562.26 9:46,April 02 2015 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 870 1060 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1060 1240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1D-146 15May14 T1 MW )4991 From Depth,o Survey/Plan tool 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 39.50 1700.00 113-146wp07(Plan:10-046) GY,-GCsS 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 - - 1420 1703 OD 2]00.00 10-146..Po](Plan:,6146) MWD 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 1700 OD 3019.11 10.146wp0](Plan:16146) MwO.1m-ac-cn2-sc 9379.51 90.00 158.49 3877.60 -5.48 5876.86 2.50 83.02 4012.02 1D-146 15May14 T2 MW 1420 1600 3919.11 4519.11 1D-146wr97(Plan:1D-146) MWD 3019.11 7611.66 10-146wp07(Plan:10-146) MWD4IFR-AK-c0.7-Sc 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7611.66 9311.66 10-146wP9](Plan:1D-146) MWD 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 7e11.6e 164>1.69 tnt46wP%(PI.n:10-146) MwD.im-AKcazsc 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 1D-146 15May14 T3 MW 1600 2230 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW TVD MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW 2850 3480 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 3791.60 16471.69 4 1/2"x 6-3/4" 4-1/2 3480 -- 4100 4100 4730 4730 5350 - 5350 _� 5980 0/360 5980 6600 A...)„,,,, ,°®�%-- �!r 75 6600 7830 -30/330 ��®'I 70 \ 30 7830 --i 9070 .��s�'_� 65 \�v`��� 9070 10300 60 N4% 10300 11540 -��` 55 *\ 11540 12770 .�� �•�� 50 �`,\• 12770 14000 �/1,�`►�� � \ 14000 15240 -60/300 - *11/4 �..-.,4®, A.r )♦ 1 ♦ I ✓ ---_ ------"--.N ,`\ 60 15240 16472 -90 ',Al./Ali/A Aite4V4kak iAteaffjtk#A ' ---''''' iiinfittilltilitti 016110arriii ------- ' 1‘ A Ilk, ,, k Alth.A00---14iiiiiiiiikillii /,' , VI Nria7/41/4,"7' ff, ,44/Aits•44%-.1.09,A1.,,,,,,..ric rP.-I" laiipv,„ ,4 , 1 . ,,,,,.#4.,,,,40....„.....,,,. \ /270 A. � .® _` • imill __ 1,‘C4------1,/ ! i - 'Off ) L.„-;--1-....77.-_,--........ \ ' itabh, I", dip ir 51:17.41Mil so it lt,* \\ Nikalk11110iir \ ite \ \\ .,2.. 20 ..,-i 1\ lip 2 5 J 11/ff"/ / . wAstlfAllifip6v41 r /ilii/!/, ♦ i4 1,,�,�� � L.IM:%11,14 I I 141,...a 1 d 1 ISlil // / /ems♦I♦ `r 4.11115 �,h 11 -120/2401111‘ 11 �I /aia1',iI to; 1�'10 OW. �t141,t1'/��,, '�) 120 101P1 s - 411kigittfOt • Op il• #111,// 4." N......,..,,,, .........,. ,,..t.... . 4 , ANIX10.1tiv'-.14,11-,-411,1:4i,'-4rz"1/1 ell . ,-s-- -150/210 _�`�i;�p!i�+i4 150 1 1i It -180/180 .4- 6„1214-14215 "Ar 264M1P02140 -f� 10- i- -0- >•42II ,0,Q„02,00 -x 121 -s -x $ WP4106Ven41 44 14211 19 o- �- , 2 e -s- 11.4211 $ 10 " Io -9. ,o 102 -e- 10 VI 44- 1 .ID 44- ID 2 19 X 19 44 19 ID tr -9. , ;:2,0,00 -eno n - -tr- ID 100 t 10 o 10 -tr ,4 -x- n . 4 10 1211.1, $ 10 130 10 133 42 a a -0- 001 VI $ -a- I0 a 10 102 10 -+- 10 + I .10.1 -tr- 19 - 19 � I9 2 -_ 19 43- In n � ;o •4.10 122 10122 42 "e- 10 -o- ,o � 10 $40 10 40 1040 44 ,!r 11444 -- ,o -� 19 117 0,P61 VI -tr- 10 41.1041.104141 $ ',E2.,H;20', Va il ;8,1;.11,1114,; 111 119 I ;BZ.;B LILT,, 3 1 K.1111.;g.,`;t 0 MD Inc Azi ND +N/-S -FE/-W Dleg T VSect Target 4U SLtf 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 1 D-146wp07 328.00 0.00 0.00 328.00 0.04 0.00 0.00 0.0 0.00 328 510 707.90 4.18 110.00 707.56 -4.74 13.01 1.10 110.00 12.34 2000.00 To 3000.00 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 1650.92 25.05 84.30 1612.60 -41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 690 870 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 562.26 9:46,April 02 2015 638223 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 870 1060 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1060 1240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1 D-146 15May14 Ti MW lapin From GaPm To sunaymMn 7001 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 39.50 1700.00 1.-146wp07(Mom la-146) GYo-GCss 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 1420 1766.06 2700.00 113-146a867(Plan:16146) MVO 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 1706.00 3019.11 16146wp07(Plan:16148) MWD.IFR-AKCAZSC 5619.11 4519.11 10-146wp07(Pian:16146) 144/139379.51 90.00 158.49 3877.60 -5.48 5876.86 2.50 83.02 4012.02 1D-146 15May14 12 MW 1420 1600 5019.11 7011.66 1D-146wp07(Plan:16146) 60103.1F13-0X-C.-SC 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7811.66 9311.66 10-146w1207(Pian:16146) WO 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 1600 2230 ]ansa 1647169w lsa lasO0 (3Man:10-146) Mwen w -uccu sc 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 10-146 15May14 T3 MW 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW ND MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW 2850 3480 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 3791.60 16471.69 41/2"x 6-3/4" 4-1/2 3480 4100 4100 4730 4730 5350 5350 5980 0/360 5980 6600 150 6600 7830 30/330140 30 7830 9070 130 -�1\ 9070 10300 !%! 120 10300 11540 110 �� 11540 12770 -- 100 #�� 12770 14000 90 �� ����� 14000 15240 60/300 �� 80 --=------ �� IOW iiik 60 15240 16472 70 ifti VA 60 Iiiptt$ 1111W 50 -------,, I A( ito .0 /,//.. / /7 40• Alik V, r------31 21 Ittitpfilifor vv •1 - .! ffi It i ,7). 9011.-141APB71 90/270/ 1 1111 le �lfaralgi fi , hq�, IIID-141 APB n/ 1 111\1\ 21 `irlr II01' I • pd-mi uPBz \�/V A) 1\ 31 �Ij�witatI ' ria - - \N ����OP 1D-141L' �l1D-141A 60 ,/ 0 ,, , , Alific1711,11:170/11 31 D-141APB 50 70 -120/240N \ /�;;0w20 Arcimi120 130 (-'�0111111111W'��. -150/210 -- 140 '1.�r 150 150 .-'�i I.� �1 D 301 11D-3001 -180/180 -;- , o-„Ia 1.1114 Y -a- 1.126.17,:10-1200,10-12,0,02)w � , -2- ,.30.,036,1.%V4 43 1,12 11 17701.722,03),�7,03), -x- , ,l20.,2 e 0�2s,02022 ,1., 19, 'a -a- ,0.08,,03AI036WP 10-38,2,1,0 V1 .19-, ,0119,16119,;4;;0 t , 21.100- 136,130-.104611 V3 e -g. 1a $ 1.129.1.120 1.129 Va $ , 610-1412131,16141,1 -e- na-a,,D3612,D361E v, -- .4- 1.12,1.121.12 V9 -e- .ua 10130 as 2614O -X- A- :10-1 + 113-12 11112, VO -,,e- , -$- , .1421.142F0720 t 1042. 4r ID 91,1.121_117131w -)- 113-1,21.132, }10.132 V2 - ,D 4r 10 D-so-a ID.9Taw -x- } 1.12 1.12L2 1.1212 V0 -9- ID Io-no no-153 22 -e- ,0 s 10 201 an } 1.120,,o-,2410-120 w -e- 1.33.10-133201.10-1332211 22 .0. ID ,ID-sq ID3ats - ,W0.,.36.,.96 v2 } - -!a- ID -X- 1.134.1.134,1.134 22 -0- 1.30 1.300,11030U V2 -I- 10..,1Daq ID.ana - -9- ,W2210-,a216122w3.5 4 .110.13522 4i0 t ` -A-. 10-20.10-20.1040 24 - 122,1 10-123,10-123,0.1 123 22 1.141,1.141,10,141 V2 -kr t ,10-3,1 01 -e- 1040,10-20%10.400 V1 -9- 106- -2- 113-124,1.124,10-124 w -6- t IPBI 21 -d- 1041,1.41,1041`il $ MEM. 31 /;1;,,B31,1B11,91N X K. 1 ,81,,,CA,; llt MD Inc Azi TVD 39.50 0.00 0.00 39.50 +N/-S 0.00 +E/-W DI eg.000.00 Tf� VSect Target 0.00 0.00 41) 3125 1 D-146wp07 328.00 0.00 0.00 328.00 707.90 4.18 110.00 707.56 0.00 -4.74 0.00 0.00 0.0 0.00 13.01 1.10 110.00 12.34 328 510 3000.00 To 5000.00 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 1650.92 25.05 84.30 1612.60 -41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 690 870 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 562.26 9:47,April 02 2015 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 870 1060 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1060 1240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1D-146 15May14 T1 MW 1ap1n From Depth To Survey/Plan roof - 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 39.60 1700.00 1G-146wp07Mem 1130146) G1QGCs0 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 1420 1700.00 2700.00 113-1464.p01I 1021 117-140) Mwo 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 3019.11 4519.11 10-146wp07(Ram In-146) MwodPa-Ax- SO-sc 9379.51 90.00 158.49 3877.60 -5.48 5876.86 2.50 83.02 4012.02 1 D-146 15May14 T2 MW 3019.11 4811.61 10-146wpo71Plaa:10-146) MWD v 1420 1600 3019.11 7611.66 113-146wp07(Ptaa1 10-146) 66w0r4242-022cAz-6c 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7911.66 9311.66 10-14600p07(7la7:10-146) MWD 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 7911.66 1647109 10.146wp07(Flan:10-146) MWGrIFA-AK-CAZSC 1600 2230 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 1D-146 15May14 T3 MW 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW TVD MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW 2850 3480 2515.60 3019.11 103/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 3791.60 16471.69 41/2"x6-3/4" 4-1/2 3480 4100 4100 4730 4730 5350 0/360 5350 5980 5980 -^" 6600 150 6600 7830 -30/330 140 30 7830 9070 �.. 4.% 130 10°4 9070 10300 � 120 /ii'Ai WA` 10300 11540 .1 110 *.ira1•.®�. 11540 - 12770 �•� . 100 �O����`������ 12770 14000 �'.. • 90 °�0%11 �� 14000 15240 -60/300 : f j� \ 60 15240 16472 �. . /fig1������Iror/n 0. `I j ,' ` `\1:%,i 1frei/ 6';'� /fi,4,,,007„ rrr90 4•1 ;rexikmmm,,,v",lh,„, Aingfiliiis,I 21 ;Tozossmwww14 00-7-;4,,,„ i pl 31.'��,d 0/21�G rA,N4,* 71111114antimq411 ,-;0.,irol;:;;- . 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P3604 4£ ID i - -fr 19 .121 W -)E- 6134,16124,1613402 e $ 10 30,10 3011,10 90L1 V2 -E- 16 16 $122,61221612222 013316135,1015502 -0- , $ , /344164044 $ -fr $ 10-123.161231012300 -6- , $ IP 404. VI $ 140- 40. 0-124,16124,10124 V0 -� , yg 174,V1 -Q- * 1B,tr,i' ';d° 14 I ,B�I;.:r,:si.1:;oke t 1B .1B 9,,I.i „ 119441.14,18 rA, MD Inc Azi TVD 39.50 0.00 0.00 39.50 +N/-S 0.00 0.00 0.00 0 0.00 +E/-W Dleg TF 13.01 1.10 110.00 VSect Target 4U 3Lti 1 D-146wp07 328.00 0.00 0.00 328.00 707.90 4.18 110.00 707.560.00 -4.74 0.00 0.00 0.0 0.00 12.34 328 510 8000.00 To 11000.00 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 1650.92 25.05 84.30 1612.60 41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 436 -41.54 432.82 690 870 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 562.26 9:48,April 02 2015 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 870 1060 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1060 1240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 10-146 15May14 Ti MW "-' 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 M°th 3900 .Depth 20 o-100wpoT(POv:16148) Tool-Gcss 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 1420 1760.00 2700.00 1D-1460p07(Prem:10.146) MWD 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 nao.00 3019.11 161460,907(Flew 10-1ae) Mwwim-uc-cAz-SC 9379.51 90.00 158.49 3877.60 -5.48 5876.86 2.50 83.02 4012.02 10-14615Ma 14 T2 MW 019.11 4519.11 10-146wp07(Pren:16146) MWD 3 y 1420 1600 ]019.11 7811.66 1614600p07(Pran:16146) MWD,F13-2.14-CAz-sc 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7811.66 9011.66 10-taowp07(Rom 16146) MWD 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 7811.0)8 1847199 1614eVm07(Flan:16146) MWD -uc-cnz-sc 1600 223010515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 1D-146 15May14 T3 MW 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 10-146 15May14 T4 MW ND MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW 2850 3480 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 3791.60 16471.69 41/2"x6-3/4" 4-1/2 3480 4100 4100 4730 4730 5350 5350 -- 5980 5980 0/360 [1D-41 Intermediate Sidetrack Option Wp06(02/27/OL,1 5980 6600 150 6600 7830 -30/330 140 30 i 7830 9070 130 9070 10300 0x8 85 120 10300 11540 110 11540 12770 '-'2,: ' - - 100 12770 14000 .1 14000 15240 -60/300 60 15240 16472 : z6 )60 i.4-90/270 � ' 90 \iiiiiii4iiiiim,.6s //7%70 -120/240 80 :.............________7jr, 120 90 100 110 120 130 -150/210 140 150 150 -180/180 4- 1 onoz,o„u vs -� 0001.000)00 - ' 10-141, .4- ma ma ma w 9 2m�,orw -* a,VI $ - , -e- , 10-32,laaawp4,a,�waV, -t $ i- , L1PDOna-14121Pa2Yw2 -e- ,a.max,,ala�,w $ -8- 10 $ ;o o-;aananaa4 $ 10) Aa1.11141pa,V2 -E ma6.10aR2.,0a.201 ,.« -94 0-1x1'2-z'WW W ana,ln0 W 9 , o-,.:1614200 if -43- I :121-1 $ -dr $ 14144 14v,1044near w $ $ -A- m -3- ID-139,16M.o , ,s200 $ ,0 r}- ,D-5119-971-9.w rn2 Vs 8- r -4- m no-1 la eax2 vow w -B- ID-moo-In loos v0 4- m a $ ,o r0),V, $ r :10-1 $ 10-nal o-iso.1a12ow $ r ,v2 $ , -$- 100)0,10,0 no as vs su $ r . -A- r0) ID-13,10-15,1013002 9 $ 1030.10.301-+1003LI V2 } ,o-re '44. $ 119-122ro12210199 W 'O m on,1.35 w $ 10 oat,163945 $ 10-40,10-40,04004 'f- $ 10.193,12-193,10-193 W $ ,te $ 10+01040011.0001 $ 14.. -A- ,0.na,w2a,0.na W -Q- 1081 V. 104,.,04,,,0+1 VI $ 1811111 '°d.,2 w S 111a1.111a14,1B 441A g I :Et,EIM,v, 118:::1311.Y.Ilit • MD Inc Azi TVD 39.50 0.00 0.00 39.50 +N/-S 0.00 +E/-W Dleg TF 13.01 1.10 110.00 VSect Target 0.00 0.00 0.00 4U .5123 1 D-146wp07 328.00 0.00 0.00 328.00 0.60 -4.74 0.00 0.00 0.0 0.00 12.34 328 510 707.90 4.18 110.00 707.56 11000.00 To 16471.69 1207.90 16.67 106.98 1198.34 -32.02 99.07 2.50 -4.00 90.98 510 690 1650.92 25.05 04.30 1612.60 -41.30 253.68 2.60 -55.00 203.22 1761.30 25.05 84.30 1712.60 -36.66 300.19 0.00 0.00 231.54 2879.59 69.00 52.00 2465.60 330.71 989.27 4.36 -41.54 432.82 690 870 4470.45 69.00 52.00 3035.71 1245.08 2159.62 0.00 0.00 56226 9:49,April 02 2015 6382.23 72.00 87.00 3691.97 1859.22 3816.96 1.73 90.98 1243.41 870 1060 6677.75 83.69 94.41 3754.19 1855.26 4105.10 4.65 32.67 1442.82 6723.11 83.69 94.41 3759.17 1851.79 4150.05 0.00 0.00 1476.01 1 060 1 240 SURVEY PROGRAM 7811.66 88.00 145.00 3843.60 1330.23 5061.47 4.65 87.40 2479.05 1D-146 15May14 Ti MW 96911 From 0np61 r Survey/Plan roof 7831.66 88.00 145.00 3844.30 1313.86 5072.94 0.00 0.00 2498.84 39.50 1700.00 113-106wp01(1760n:10-146) GTO-GC-SS 7935.30 88.57 146.99 3847.40 1227.98 5130.87 2.00 73.97 2601.16 1240 1420 1700.00 2700.00 113-14600701(Plan:10-146) 99W0 8916.17 88.57 146.99 3871.81 405.67 5665.03 0.00 0.00 3566.85 1100.00 3019.11 110239107(PIen:10.146) MW13-.1FaA40410.2420 9379.51 90.00 158.49 3877.60 -5.48 5876.86 250 83.02 401202 1D-14615Ma 14 T2 MW 3019.11 0519.11 16146wp07(PIan:1614) MWD y 1420 1600 3019.11 7811.88 16/48wp07(P727:10-1462) MW1341FR-203.c02sc 9493.69 90.48 155.67 3877.13 -110.63 5921.32 2.50 -80.39 4119.24 7811.66 9311.86 16146wp01(P27:16149) MWD 10022.14 90.48 155.67 3872.73 -592.15 6138.99 0.00 0.00 4619.85 1617.46 16471.69 o-19610701(Ran:10-100) Mwwo-a-uc-CuSC 10515.46 90.94 168.00 3866.60 -1059.95 6292.46 2.50 87.76 5066.64 1D-146 15May14 T3 MW 1600 2230 10930.53 90.95 178.38 3859.74 -1471.47 6341.61 2.50 89.89 5401.13 CASING DETAILS 11328.51 90.95 178.38 3853.16 -1869.24 6352.87 0.00 0.00 5699.73 2230 2850 11367.83 90.68 179.33 3852.60 -1908.55 6353.66 2.50 105.46 5729.01 1D-146 15May14 T4 MW TVD MD Name Size 16471.69 90.68 179.33 3791.60 -7011.68 6413.73 0.00 0.00 9502.17 1D-146 15May14 T5 MW 2850 3480 2515.60 3019.11 10 3/4"x 13-1/2 10-3/4 3843.60 7811.66 7-5/8"x 9-7/8" 7-5/8 3480 4100 3791.60 16471.69 4 1/2"x 6-3/4" 4-1/2 4100 4730 4730 5350 5350 _.--- 5980 0/360 5980 6600 150 6600 7830 11D-41P__.I 30/330 140 30 7830 - 9070 /_l1 D-41 Pell 130 9070 10300 _ -10 411 10300 11540 Ailialltawd1110110,'"Alk, 1446. 11540 12770 �.m12770 14000 / �� - rie , 14000 15240 -60/300 // 80 60 15240 16472 60 /,, 50 40 31 / 21 -90/270 90 1 lilt 2 1 ... 31 40 '//// 50 /' 60 80 ;= -120/240 120 •1 100 //// 110 %,, 120 =� 130 -150/210 140 150 150 -180/180 -3- , 01110101112 05 -b- , 261(.302)10 4" , + 1032,1099 V4 9 *42,11 P35�7l09(W -)f- , 10, iE , $ ; 1036.103WP2,9611.4 VI -x- 942,1 -g- , -e 012010-1290022 t 1 ,1,PIM ID 14111PP62 VV2 10179,10119,10119 02 43. IV In,10129,1012902 $ 10 141,10141761,10141001 V2 4E) 106,103912,10x51201 44' 10-12,10-121012 V9 '0" 10 01 37 Va 3 90,1019002 t 16142,10 142 00 7 --e-t -A- 10 1,10131,10131 02 $ 10142,1014010142.07 VO •-1... -37,103711,103711 II '1r 10-12,10190170,1012 701 00 -}• 10192,10132,10 132 V2 - 10 "A- 10 37,10.902103712 V9 -X- .1E- 10-12,10121.2 101212 00 $ 10 1.3.lam,0,3302 -A- 1 9 -A- 1 P0101 10 120.10120 1 } 0 120 W 1013,10 133701,10133701 02 '0- 10 -} 10361032,10x9 W.3T� -+" 10.1 4r. 10-121,10121,10121 02 -X- , 1,1033011 V2 -Z- 1084,1039,1039 W -34 122,1 10122,10-122 10122 20 l0.136,10139.10-135 02 -0- 10 32,10 32,1032 V6 10-40.10-40,1040 04 -16- 192,1 46- 10- 16126 10123 W 4.12. 1 '' 10-40.10200.10400 01 $ 1468 10124.10124,1012420 -3t,- -*- 1 1701 W t $ 111.130:11/1. It 111:.: 1311,Ili 3,st X 111.1.11;711,v,10921, B11,,B,L1,l 34;[,v, I ,8:,,,81,681,11;g8z8, Errors Report Pool Report • • L OZ-3 L J�°y O #a O LO /13,,,. 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Region: [alaska v C Latitude/Longitude [Decimal Degrees A C Latitude/Longitude [Decimal Degrees _Id C UTM Zone: F--- E South r UTM Zone: [True E South 4State Plane Zone: Fei .,. Units: u1-76—E, C State Plane Zone: IDTrue .„. Units: .1;111 .E, C Legal Description(NAD27 ontyj 4- Legal Description(NAD27 only) Starting Coordinates: Legal Description X: [1700702.85 Township: roTr iN . Range: 10.10 [E .,11 1 Y: 15959105.33 Meridian: [U zi Section:[23 1 I IFNL z:_i r31iT2455 [FEL _LI1418.132268 ..._......, Transform Quit Help 1 —... .. . , .. ‘,.. _. i 1D-146 Intermediate Casing I t . 1 taCPAI Coordinate Converter iit From: To: Datum: [NAD83 -. Region: [alaska A Datum: )NAD27 A Region: lalaska „......1 C Latitude/Longitude I Decimal Degrees ,I C Latitude/Longitude [Decimal Degrees A C UTM Zone: 1-- r" South r UTM Zone: True 1- South [True 4- State Plane Zone: 14 ;[. Units: 1s.iL „,, .1 Units: IFTL1:j r State Plane Zone: C , egal Description(NAD27 only) (;" Legal Description(NAD27 only) Starting Coordinates. Legal Description X: h70575300 Township: loll [N .,.J Range: I 1010 11Ar Y: 1.5960476.00 Meridian: [U .... Section:11 3 [FNL 14264.1628 IFEE ;1 1636.40659 , . Transform I Quit I Help I „..............,.... .......................,.... f.. • 1D-146 TD r- tc-DS110,043,n. CPAI Coordinate Converter I From: To. 1 ' Datum' [NAD83 v I Region: Ialaska . Datum: ..L INAD27 .,I Region: I alaska I C uLaTtitude/Longitude [Decimal Degrees _......i r Latitude/Longitude [Decimal Degrees , CmI Zone: 1 r South 4' State Plane Zone: I1E, Units: LI"--4;T ., CC StateUTM Plane Zone:Zone: !True E South True • Units: rus:ir , --- I— Legal Description itJkLi 27 only) r.._...— Cr Legal Description(NAD27 on ) Starting Coordinates: Legal Description X: 11707172.00 IN Range:,.." Range: 1 I011 IF" [ Y: [5952146.00 Township: l011 Meridian: [u .I.3 Section:rio --- FFE [2047.0100FITCE. [4271.4345 Transform Quit I Help I tv , 0 • Tollerable Collision Risk Worksheet • Conoc PhillipsConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Generic iiartleof`scenandfOttiar . " k Em. Colliston of the 1 D-146(Single lateral in West Sak 0 sand)with the existing West Sak producer Risk Worksheet 10-184�eSrCr.•t amr` sec �`` b all' "o "7w c��'to (w" 1 "cos cplllsl o[�I�ie,. 4 ��I e,.. Aye��•�>x 7a.�o- � s,� i .� based on Rev.1-29 Jul 99 Well 10-146 fails anti-collision with 10-184 based on WP07. There is no immediate danger to life or impact on the environment if well 1D-146 intersects 1C-184 because 1C-184 is currently shut in Use this sheet to describe a well Interference scenario where(IRA due to an existing casing leak. 111D-148 intersects 1C-164 there would be damage to the 1C-184 may be applicable.Check first that the scenario really is different well and then the well may have to be replaced. 1D-146 would also have to be plugged and the from those described on existing worksheets. intermediate section redrilled. No risk of a well control issue exists because if 10-184 is hit,we would be colliding with the well with kill weight fluid in the hole. • .$Vies V Kelsey Hallford � i ,' 1.. r Or)aed:,.,tac Daniel Bearden ,.. te s Do the consequences Are the STS P of collision include a risk to personnel or tile consequences •" of collision environment? Major risk *la CO rne. 5 WWlYcl5 ,�a O E"� �l et et o ,�e i.^t.h Cost-ore-ofitalgo: No HSE risks exist with 10-146 intersecting 10-184 while drilling as 1C-184 would be intersected ata depth with kill weight mud in the hole and it will also $10,000,000 be shut II. An economic concern exists and It would be the cost of plugging back and sidetracking the Intermediate section that we are drilling as well as further damage to 1C-184. 1C-184 may have to be replaced. 0 out. �e . ob 61 0' � . . • t e� t o tataet ofatcei On C $10,000,000 Ti'41�U� �J ..�. e9iIIlSra a t` ore 10- iiVi` O5 ... Is there a practical way to substantially reduce :101P70703. '450-1.°41 •Yes either the probability of o No R an collision or the severity V= $33,200,000 of the consequences? ccep�l . , In to s rf co list•It re's P . p o.',e O. . u o •s ,�toa oft e10 • P? .ttot-Oe. ? Ile1ne� pV f t4 �;05) F= 0.01 E fl;tb '6100=eost'o. V= $0 r.@ �� . .. tNTRA n VF/C= 0.0332 GI e` `'h"tti'e" t In§ill�, o° a'"e§'ti:l at °t y+�ld ; IF V F > 1 Ihen close approach tolerances need not be eel an t rE s us hes vin�str t #` ,qo r el ig If v F t e s'ti.utWel lie nsl(iei st r e i e[— U s. • '. .;� r ,., �G 1 � �., ze� C < 1 Ihen Tolerable Collision Risk 1 in C!V F M= 20 • F='I /M= 0.05 Tolerable Collision Risk= 1 in 30 • 0 ConocoPh i I I i ps ConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska Ak Tolerable Collision Genenctiariieofcena 'lfto k ,T€ tatM ( aF a ,, Collision of the 1D-1218(Single lateral In West Sak D sand)with the existing West Sak injector 1C-190 Risk Worksheet SOIPt ax oog--ln r, 0 cl� e Sete a l`t Itst �r"g14 a.•a sLo. • cg1e s E >, .? n 4. ' `sa* based on Rev.1-29 Jul 99 Well 1D-146 falls anti-collision with 1C-190 based on WP07. There is no immediate danger to life or Impact on the environment if well 1D-146 intersects IC-190 because 1C-190 will be shut in as Use this sheet to describe swell interference scenario where ORA we drill the intermediate section on 10-146. If 1D-146 Intersects 1C-190 there would be damage may be applicable.Check first that the scenario really is different to the 1C-190 well and then the well may have to be replaced. 1 D-146 would also have to be from those described on existing worksheets. plugged and the intermediate section redriled. No risk of a well control issue exists because if 1C- 190 is hit,we would be colliding with the well with kill weight fluid in the hole. ii'reP2 ;,et r t4Kelsey FtaAford `,0 �� " U ��. Daniel Bearden L..A Do®Na consequences sTo p � of collision include a pYes Are the One risk to personnel or the consequences environment? of collision Major risk 0 Yes coIsona''e ititiiWc6 `"+\" ' , re*en o> t,: ' YE: Cast COBlslo .iif oar No HSE risks exist with 1D-146 intersecting 1C-190 while drilling as 10-190 would be intersected at a depth with kill weight mud in the hole and It will also $10,900,000 be shut it. An economic concern exists and it would be the cost of plugging back and sidetracking the Intermediate section that we are dating as well as damaging to 1C-190. 1C-190 may have to be replaced. 4 • co 1,11 pip li3 }o o s o`i.'4 a s6 f t:.Il.6, Fo 1: 7` m ria FkCO IISla11, .sj l C= $10,000,000 Itr! o S a e0C >, o e .. AP c4**4.44';'..i g4' of is ost Is there a practical way 0yes to substantially reduce ®No fit.-'--,'Nt . . re either the probability of I to p annex e. t: collision or the severity V= $33,200,000 of the consequences? aeta,eU2ar a. • ma a 49.9201.,9:;:. e ',..!,9,,c."•.,.. 1...< •!, t e r e,� , Nab ' yO$ Pre ' oto s e 4 G., sP.J.-Q;149)40aes.. t..1, t j F= 0.01 y E ut at'10-7tot Is`lift t� 'tS hS v e V= $0 • ' • •• i,< V F/C= 0.0332 1 1 " xwev� i e If V F > t then dose approach tolerances need not be set 94"1.A. o Circe ��t� a�ave es�tl D e b i o pp rhy 1�e5�s e s a. Fa 4t etl� If V F qe s elgh 1. s Ise G ttei 0 .� �l;. � ,t{s�_��+ �,.; w�-r.. � 4 ,��.., "r'xRli• C < 1 then Tolerable Collision Risk=1 in C!V F M= 20 1 F=1/M= 0.05 e Tolerable Collision Risk= 1 in 30 • s Conoc PhillipsConi llips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Genertc:riarlle ofseer3ano ,xf� #�t�"k s: Collision of the 1D-148(Single lateral in West Sak D sand)with the existing Kuparuk producer 1D41 Risk Worksheet 9 Erol, = gel -,A S; cors ar c eirj.a,. "" ketol al0:16 tfte"`� s try , k ie •o yred'uc ng^ e s s s,q, a ort m.... € based on Rev.1-29 Jul 99 Well 10-146 falls anti-collision with 1D-41 based on WP07. There is no immediate danger to life or impact on the environment as we can use geological certainty to be certain we will not hi 1D-41. Use this sheet to describe a well interference scenario where ORA The anti-collision"window"of 10-148 with 10-41 is 3789'SSTVD-3872'SSTVD(these are the may be applicable.Check first that the scenario really is different depths of 1D-41) The elevation that we are drilling 10-146 at is 3751'SS-ND which is in the D from those described on existing worksheets. sand. The C sand lop Is 3775'SSTVD,meaning The anti-collision window starts below the C sand lop,so we can use geological certainty of staying in the ID sand to avoid collision with 1D-41.1D- • ' 41 will not be shut in while we are drilling 1D-146. ��a.,..;,6-',�s Kelsey Halliard � k AtiflD �//� Ze. . �.. Daniel Bearden k )_.k fk Do the consequences Are the SF0 p ©"a of collisionn include a ®Yg O"o consequences risk to personnel or the of collision environment? Major risk `.Jts a-:*0;. 4s e[iccso .` ,� � egess OvPs e.ii I. �`'4441:4•.:41:!:, 74 . .!�1,,; f3gsl'of:Colll$1on,..A:: No I-1SE risks exist with 10-148 Intersecting 10-41 while riding as we can use geological certainty that we wit be staying In the D sand as the anti-collision $10000300 window with 10-41 occurs below the C top.An economic concern exists and It would be the cost of plugging back and sidelracking the lateral section That we are drilling as well as damaging 1D-41. 1D-41 may have to be replaced. `0, CO.0.A�it .r+a.a. '::ii.;-:41116.!A 's8 a q �\ VE L at '1 fi to a "SlskyU C= ::,t0,_:":6611:,s cos .e e'.17-1,,,,. o � • ' .L'•i- t'''t-e rd a t: $10,000,000 f9 e. a cox With 19° .°.;�,,�¢,!:,'„az,;-,s.,.• 7, 7,i: Is there a practical way to substantial) reduce Est'•ate�t 'f PUHA a Oyrs either the probability of ®"� gal a Pla ne wwell collision or the severity V= $33,200,000 of the consequences? w 4cceptlsg . I Iter '�afl o a e ,fie of*te, ' ,' p�r n, e • t �fon, � a to-12.t....4o o o al PV,a e s y.0 repare o 01 ms �(jJi e i O 5)r. . i- ; N.. i + F= 0.01 isti aiellte a afcosf., �a ttie ly recti cin V= $0 e.Gds.- . •� . at 4 V F I C= 0.0332 1 .P'"''V '�"�' "`"` "" �'''°` �''� "'� ° "'T' If V F > 1 then close approach tolerances need not be set l en ttle.0 cr a Irl m e above est ma es'�•`y�rgtiV :9'�" .?✓..te k.. �1't(k�-x�.`"" C kW){RWIS. ngs rn kTifit teducl It V F t S thy. el e rls lt5e G ld e2D} �tl C e 1 then Tolerable Collision Risk=1 in C f V F M= 20 F=1 /M= 0.05 ' Tolerable Collision Risk= 1 in 30 As - built REV DATE BY CK APP DESCRIPTION I''.'-''—'''-'='='''' ''.4'---''''-''''''''''DATE CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS N 33 I 34 35 36 31 32 GRAPHIC SCALE T12N i0 100 200 4100 ' __ _ I sKIC T11N w 4KUP RUK 3 2 1 6 MS 24A%5 1 inch = 200 ft. AIRS -IP NI S=-113 oPT •Ain 10 M — "E'''' I• Si C SP/A/E •_ s tiF 11...i. 12 7 • ROAD % ttl PROJECT )73.--"NE ITE B 1\i, LOCATIOT'. 17. 16'; 15 4?y,4 ; 13 _ago 18 DS1 D I ; '�„ I (----\ VD'1E\ DS1 D�: 21 R2 23 - � �� �24 I9 20 �� • 1 VICINITY MAP 12 • 14 SCALE: N.T.S. 1°1 . 102 103• ®����aVi ll, • 140 . r 105 s 106•• 2 �.5�� ,��+ ,08• 107 . p;•.. • • 109 '� ��' 110• �.•�'' 4 YYY � ♦ 141 S 3"14 13 — i �`' 49th �` � 112: n3 23 24 '. 1..0 116• -\,17 118• 4 sJEREMIAH F. CORNELL/ u: r 9• 119 ��S�' LS-12663 •• J�i 120• �I�F...Zs/Z/41,5-' 5�� ,22. 12, e4 Od....,),4 •••'•'1400. • • 123 145® 4,,;FESSION '-. ' • 5 142® it\\�►�* 13 • 124 1 125• 430 127• 126 14600 • 128 SURVEYOR'S CERTIFICATE / 17 • 6 •28 • 129 •30 / HEREBY CERTIFY THAT I AM PROPERLY REGISTERED 131• 130 •32 AND LICENSED TO PRACTICE LAND SURVEYING IN • 132 133• •34 THE STATE OF ALASKA AND THAT THIS PLAT • 18 37 0 36 REPRESENTS A SURVEY DONE BY ME OR UNDER MY 1340 19 DIRECT SUPERVISION AND THAT ALL DIMENSIONS • 135 39 0•40 AND OTHER DETAILS ARE CORRECT AS OF 20 • 10 41 •42 , FEBRUARY 20, 2015. 21 • 11 • 8• 136 137• • 138 139• _----7<1. \ ` j c,.. LEGEND: k_ �Q° ® AS-BUILT CONDUCTOR LOCATION ID EXISTING CONDUCTOR LOCATION 0LOUNSBURY o & ASSOCIATES, INC. SSURVEYORS ENGINEERS PLANNERS SEE PAGES 2 & 3 FOR LOCATIONS IV-- AREA:1D MODULE: XXXX UNIT: D1 ConocoPhillips DS1 D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. I PART: REV: LK6104D33 12/18/00 CEA—D1 DX-6104D33 1 OF 3 I 6 REV DATE BY CK APP • DESCRIPTION REV DATE B CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS NOTES: 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 6. GEOGRAPHIC COORDINATES ARE NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN 7. DATE OF RE-DRAFT: 11/30/00 SEA LEVEL. THIS PLAT IS A RE-DRAFT & CONSOLIDATION OF EXISTING DRILL SITE CONSTRUCTION DRAWINGS 3. ALL DISTANCES SHOWN ARE TRUE. NSK-3.5-1, CEA-D1DX-6104D10, CEA-D1DX-6104D13, CEA-D1DX-6104D15, 4. BASIS OF LOCATIONS AND ELEVATIONS ARE DS1D CEA-D1DX-6104D16, CEA-D1DX-6104D18, MONUMENTS PER LOUNSBURY & ASSOCIATES. CEA-D1DX-6104D20, CEA-D1DX-6104D23, CEA-D1DX-6104D26, AND CEA-D1DX-6104D28. 5. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 14 & 23, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. ALASKA. CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 14, T11N, R1OE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'Y' 'X' LAT. LONG. F.S.L.F.E.L. PAD 0.G. 1 5,959,904 560,490 70' 18' 03.67" 149' 30' 36.26" 240' 595 70.8' 61.1' 2 5,959,785 560,490 70' 18' 02.50" 149' 30' 36.29" 120' 596' 70.8' 62.1' .3 5,959,665 560,490 70' 18' 01.32" 149' 30' 36.32" 0' 597' 70.7' 62.0' 12 5,959,888.87 560,490.53 70' 18' 03.521" 149' 30' 36.243" 224' 594' 70.8' 61.1' 14 5,959,873.87 560,490.50 70' 18' 03.373" 149' 30' 36.248" 209' 595' 70.8' 61.2' 101 5,959,859.23 560,490.42 70' 18' 03.229" 149' 30' 36.254" 194' 595' 70.7' 61.4' 102 5,959,844.00 560,490.59 70' 18' 03.079" 149' 30' 36.252" 179' 595' 70.7' 61.5' 103 5,959,829.35 560,490.30 70' 18' 02.935" 149' 30' 36.264" 164' 595' 70.1' 61.7' 105 5,959,798.99 560,490.57 70' 18' 02.637" 149' 30' 36.263" 134' 595' 70.5' 62.0' 106 5,959,768.93 560,490.67 70' 18' 02.341" 149' 30' 36.268" 104' 595' 70.4' 62.3' 107 5,959,753.86 560,490.70 70' 18' 02.193" 149' 30' 36.270" 89' 595' 70.7' 62.3' 108 5,959,738.82 560,490.57 70' 18' 02.045" 149' 30' 36.277" 74' 596' 70.6' 62.4' 109 5,959,723.89 560,490.60 70' 18' 01.898" 149' 30' 36.280" 59' 596' 70.4' 62.7' 110 5,959,708.86 560,490.58 70' 18' 01.750" 149' 30' 36.284" 44' 596' 70.6' 64.5' 111 5,959,693.95 560,490.60 70' 18' 01.604" 149' 30' 36.287" 29' 596' 70.6' 64.5' 140 5,959,813.97 560,490.55 70' 18' 02.784" 149' 30' 36.260" 149' 595' 70.7' 62.0' 141 5,959,678.83 560,490.62 70' 18' 01.455" 149' 30' 36.290" 14' 596' 70.7' 63.2' CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 23, T11N, R1OE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'y' 'X' LAT. LONG. F.N.L.F.E.L. PAD O.G. 4 5,959,545 560,490 70' 18' 00.14" 149' 30' 36.34" 120' 598' 70.6' 64.0' 5 5,959,424 560,490 70' 17' 58.95" 149' 30' 36.38" 240' 599' 70.6' 64.2' 6 5,959,305 560,490 70' 17' 57.78" 149' 30' 36.40" 360' 600' 70.8' 68.1' 7 5,959,184 560,490 70' 17' 56.59" 149' 30' 36.44" 480' 601' 7a8' 68.1' 8 5,959,064 560,490 70' 17' 55.41" 149' 30' 36.46" 600' 602' 70.7' 69.8 9 5,959,528.99 560,490.59 70' 17' 59.981" 149' 30' 36.326" 136' 598' 70.6' 66.0' 10 5,959,108.97 560,490.70 70' 17' 55.850" 149' 30' 36.422" 556' 601' 70.6' 69.4' 11 5,959,078.99 560,490.78 70' 17' 55.555" 149' 30' 36.426" 586' 601' 70.8' 69.6' 13 5,959,408.94 560,490.71 70' 17' 58.800" 149' 30' 36.351" 256' 599' 70.8' 65.0' 17 5,959,318.79 560,490.94 70' 17' 57.914" 149' 30' 36.365" 346' 599' 70.7' 6Z6' 18 5,959,198.96 560,491.16 70' 17' 56.735" 149' 30' 36.387" 466' 600' 70.7' 69.0' , LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PIANNRRS IIP„/ AREA:10 MODULE: XXXX UNIT: 01 ConocoPhillipsDS1D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK6104D33 12/18/00 DRAWING NO. CEA-D1 DX-6104D33 PART: 2 OF 3 REV: 6 REV DATE BY CK APP • DESCRIPTION REV DATE 8 CK APP DESCRIPTION 5 11/27/14 KRP JFC PER K140162ACS 6 2/20/15 JFC MBS PER K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 23, T11 N, RIDE Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset 'y' 'X' LAT LONG. F.N.L.F.E.L. PAD 0.0. 19 5.959.168.83 560.491.07 70' 17' 56.439" 149' 30' 36.397" 496' 600' 70.7' 69.1' 20 5.959.123.83 560.490.97 70' 17' 55.996" 149' 30' 36,410" 541' 601' 70.7' 69.4' 21 5.959.094.25 560.490.86 70' 17' 55.705" 149' 30' 36.420" 571' 601' 70.7' 69.6' 28 5,959,309.20 560,670.72 70' 17' 57805" 149' 30' 31.126" 357' 419' 7a9' 67.2' 30 5,959,279.00 560,670.91 70' 17' 57.508" 149' 30' 31.128" 387' 419' 70.9' 68.7' 32 5,959,249.09 560,670.66 70' 17' 57.214" 149' 30' 31.142" 417' 420' 70.9' 68.9' 34 5,959,218.83 560,670.62 70' 17' 56.916" 149' 30' 31.150" 447' 420' 70.9' 69.6' 36 5,959,188.94 560,670.73 70' 17' 56.622" 149' 30' 31.154" 477' 420' 70.9' 69.0' 37 5,959,174.03 560,670.65 70' 17' 56.476" 149' 30' 31.160" 492' 421' 70.9' 68.0' 38 5,959,159.04 560,670.82 70' 17' 56.328" 149' 30' 31.159" 507' 421' 70.9' 67.0' 39 5,959,144.12 560,670.96 70' 17' 56.181" 149' 30' 31.158" 522' 421' 70.9' 65.9' 40 5,959,128.85 560,670.87 70' 17' 56.031" 149' 30' 31.164" 537' 421' 70.9' 64.7' 41 5,959,114.19 560,671.14 70' 17' 55.887" 149' 30' 31.160" 552' 421' 69.5' 64.7' 42 5,959,099.20 560,670.81 70' 17' 55.740" 149' 30' 31.173" 567' 421' 70.9' 64.6' 112 5,959,648.88 560,490.65 70' 18' 01.160" 149' 30' 36.296" 16' 596' 70.6' 63.1' 113 5,959,633.93 560,490.56 70' 18' 01.013" 149' 30' 36.302" 31' 597' 70.6' 63.2' 114 5,959,619.07 560,490.62 70' 18' 00.867" 149' 30' 36.304" 46' 597' 70.6' 63.2' 115 5,959,603.93 560,490.68 70' 18' 00.718" 149' 30' 36.306" 61' 597' 70.4' 63.4' 116 5,959,588.90 560,490.63 70' 18' 0a570" 149' 30' 36.311" 76' 597' 70.6' 63.3' 117 5,959,573.95 560,490.65 70' 18' 00.423" 149' 30' 36.314" 91' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276" 149' 30' 36.316" 106' 597' 70.4' 63.4' 119 5,959,513.86 560,490.72 70' 17' 59.832" 149' 30' 36.326" 151' 598' 70.6' 66.0' 120 5,959,499.01 560,490.77 70' 17' 59.686" 149' 30' 36.327" 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.538" 149' 30' 36.335" 181' 598' 70.5' 66.0 122 5,959,469.06 560,490.71 70' 17' 59.392" 149' 30' 36.337" 196' 598' 70.6' 64.1' 123 5,959,453.81 560,490.69 70' 17' 59.242" 149' 30' 36.341" 211' 598' 70.6' 64.2' 124 5,959,393.96 560,490.70 70' 17' 58.653" 149' 30' 36.355" 271' 599' 70.3' 65.0' 125 5,959,379.35 560,490.59 70' 17' 58.509" 149' 30' 36.361" 286' 599' 70.3' 64.3' 126 5,959,363.92 560,490.68 70' 17' 58.358" 149' 30' 36.362" 301' 599' 70.3' 64.3' 127 5,959,348.96 560,490.67 70' 17' 58.210" 149' 30' 36.366" 316' 599' 70.3' 64.3' 128 5,959,334.14 560,490.58 70' 17' 58.065" 149' 30' 36.372" 331' 599' 70.3' 64.5' 129 5,959,273.92 560,490.79 70' 17' 57.472" 149' 30' 36.380" 391' 600' 70.3' 68.2' 130 5,959,259.09 560,490.81 70' 17' 57.326" 149' 30' 36.383" 406' 600' 70.5' 68.2' 131 5,959,244.05 560,490.74 70' 17' 57.179" 149' 30' 36.389" 421' 600' 70.5' 69.9' 132 5,959,229.23 560,490.64 70' 17' 57.033" 149' 30' 36.395" 436' 600' 70.4' 69.8' 133 5,959,213.89 560,490.68 70' 17' 56.882" 149' 30' 36.397" 451' 600' 70.4' 69.0' 134 5,959,153.84 560,490.83 70' 17' 56.291" 149' 30' 36.407" 511' 601' 70.5' 69.1' 135 5,959,139.02 560,490.80 70' 17' 56.146" 149' 30' 36.412" 526' 601' 70.5' 69.4' 136 5,959,048.98 560,490.91 70' 17' 55.260" 149' 30' 36.429" 616' 602' 70.7' 69.8' 137 5,959,034.40 560,490.80 70' 17' 55.117" 149' 30' 36.436" 631' 602' 7a7' 69.8' 138 5,959,018.76 560,490.73 70' 17' 54.963" 149' 30' 36.442" 646' 602' 70.7' 69.9' 139 5,959,003.94 560,490.58 70' 17' 54.817" 149' 30' 36.450" 661' 602' 70.7' 69.9' UD 5,959,289.02 560,490.94 70' 17' 57.621" 149' 30' 36.372" 376' 599' 70.7' 68.1' ** 142 5,959,414.03 560,670.75 70' 17' 58.836" 149' .30' 31.101" 252' 418' 66.8' 65.5' ** 143 5,959,384.08 560,670.58 70' 17' 58.542" 149' 30' 31.113" 282' 419' 66.9' 65.5' ** 145 5,959,444.08 560,670.82 70' 17' 59.132" 149' 30' 31.092" 222' 418' 66.9' 64.7' ** 146 5,959,353.83 560,670.88 70' 17' 58.244" 149' 30' 31.111" 312' 419' 67.1' 65.2' LOUNSBURY ** INDICATES CONDUCTOR ASBUILT TH/S SURVEY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS `,/ AREA:1D MODULE: XXXX UNIT: D1 ConocoPhilli sDS'D WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6104D33 12/18/00 CEA-D1 DX-6104D33 3 OF 3 6 1D-1I Drilling Hazard$ ummary 13.5" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti-Collsion with 1C-184 and 1C- Follow real time surveys closely. 1C-190 will be shut 190 in, and 1C-184 is shut in all ready Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Anti-Collision with 1D-41 Moderate Follow real time surveys very closely, stay in D sand while drilling lateral and we can avoid collision using geological certainty. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. Attachment 2-1D-146 Drilling Hazards Summary.doc 4/2/20151:16:40 PM 1 D-146 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casing (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 Volumes are based on 250% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2253' MD. Client: CPA' Revision Date: March 31, 2015 Lead Slurry Minimum pump time: -240 min. (pump time plus 120 min.) Prepared by: Jenna Houston Location:Anchorage, AK DeepCRETE @ 11.00 ppg-1.91 ft3/100 lb sk Phone: (907)263-4207 Mobile: (907)223-8916 0.6382 ft3/ft x 80 x 1.0 (0% excess) = 52 ft3 email:jhouston2@slb.com 0.3637 ft3/ft x(1706-80) x 3.50 (250% excess) = 2069 ft3 0.3637 ft3/ft x(2519-1706) x 1.50 (50% excess) = 444 ft3 -1 < TOC at Surface 2069 ft3+ 52 ft3+444 ft3= 2565 ft3 2565 ft3/1.91 ft3/sk = 1343 sks (-1353 sks) t Have additional 11#on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk I 0.3637 ft3/ft x(3019-2519) x 1.50 (50% excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/1.63 ft3/sk = 195 sks Round up to 205 sks BHST= 73°F, Estimated BHCT=75°F. (Based on 2.1°F/100 ft. from surface) PUMP SCHEDULE Stage Cumulative < Base of Permafrost at Pump Rate Stage Time 1,706'MD(-1,663'TVD) Stage b Volume min Time ( pm) (bbl) ( ) (min) CW100 7.0 50.0 7.1 7.1 MUDPUSH II 7.0 50.0 7.1 14.2 Pause 0.0 0.0 5.0 19.2 i 11 ppg DeepCRETE 7.0 456.8 65.3 84.5 l Lead < Top of Tail at Surface Tail 7.0 56.3 8.0 2,519'MD DeepCRETE Slurry 92.5 Pause 0.0 0.0 5.0 97.5 Fresh Water 5.0 10.0 2.0 99.5 Pause 0.0 0.0 5.0 104.5 Mud 8.0 262.7 32.8 137.5 Mud 3.0 10.0 3.3 140.6 MUD REMOVAL < 10 3/4",45.5#casing in 13.5"OH Expected Mud Properties: 9.4 ppg, Pv< 20, Ty<20 Spacer Properties: 10.5 ppg MudPUSH* II, Pv= 17-21, Ty m 20-25 TD at 3,019 MD Centralizers: As per CPAi program. (2,516'TVD) • Mark of Schlumberger 1 D-146 Schlumberger CemCADE Preliminary Job Design 7 5/8" Intermediate (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: March 31, 2015 Volumes are based on 40% excess. Prepared by: Jenna Houston Location:Anchorage, AK Tail Slurry Minimum thickening time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.2148 ft3/ft x(7781'-4337')x 1.4 (40% excess) = 1036 ft3 Shoe Volume: 0.2578 ft3/ft x 80' x 1.00 (no excess) = 21 ft3 Totals: 1036 ft3+21 ft3= 1057 ft3 1057 ft3/1.16 ft3/sk = 912 sks(920 sks) BHST= 101°F, Estimated BHCT= 82°F. (BHST calculated using a gradient of 2.1 ¶1100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH ll 5.0 50.0 10.0 10.0 10 3/4",45.5#casing .___ Pause 0.0 0.0 5.0 15.0 at 3,019'MD Tail Slurry 5.0 165.0 33.0 48.0 Pause 0.0 0.0 5.0 53.0 Fresh Water 5.0 10.0 2.0 55.0 Pause 0.0 0.0 5.0 60.0 Mud 6.0 335.0 55.8 115.8 Top of Tail at Mud 3.0 10.0 3.3 119.1 end of pumping < 4800'MD MUD REMOVAL Recommended Mud Properties:9.6 ppg, Pv<20, Ty< 20. As thin and light as possible to aid in mud removal during cementing. 7 5/8",29.7# Spacer Properties: 10.5 ppg MudPUSH* II, Pv 25-30, Ty=30-40 in 9 7/8"hole Centralizers: As per CPAi program TD at-7812'MD (3844'TVD) *Mark of Schlumberger 0 • 1 -~� /-\4 % § \§ ( - ! ]\k/ \)\` | TB } 2III \# opi R ` . ) 11 N ( � ; }\ fL1 I• \ d [1 II _ 0 I L ! \ ) °/ i I § 3 G > ) )7 • \2 - P. 0 /a ` g± ` j | § j u) oi ( U § - \� ° " I I • , § - \ E \\ \ . $ ( \ r }) p ) ) . j. )\ \) . � . - #/ - / ? - )§ !§ �\ } iii§ e- I ' )) {§) ) / ptI 1111 2£ '~ k( § \ ®» » j[ \) §§/\ \2� 7« \\k§ §} . )% -a ConocoPhillips Draft Schematic ln!#(f W_4 Attachment zzSchematic WP07_, Alaska • • Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Thursday,April 09,2015 2:21 PM To: Loepp,Victoria T(DOA) Cc: Lee, David L; Bearden,J Daniel;Alvord,Chip; Herbert, Frederick 0 Subject: 1D-143 (214-145) Contingency due to Haul Road Closure Hello Victoria, To re-cap what we discussed on the phone: 1D-143 has drilled,cased,and cemented the intermediate string section;currently testing BOP's. However,the fluid needed to drill the production section is grounded in Fairbanks due to the Dalton Hwy road closure. Upon approval of the revised PTDs for KRU 1D-145 and KRU 1D-146,we would like the option to suspend operations on 1D-143 and drill the surface hole sections for one or both of the next two wells planed on the 1D pad. We are continuing to work the challenges resulting from the over flow on the haul road and would like to have this as a backup plan. Please call or email with any questions,thank you. Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallford(a�cop.com 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: X I Q /A- 1% PTD: o2ly - I35 ✓Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: l U POOL: i. I v6f 5 ti-K 6 r Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • CI El N a) 0 , , , u) N a) 0 U) , a), c' — c as Q U p 3 co o ca v w' 2 co to O O. N �� O a. 0O C. CO e, d a >, 3. N. N a) m. -`o , C 0 ` v a a`i . ami _ 0 o N o, 21 c , a of m @ m 3 a a) a. SC' N' E, o m. -3 O (a a _, rn pE D QN c • a)Q aN Q �, w u) w M U' O N � 2' a> j ° o6 �' c; o' a' o' a) §' �' '0 o' N, m, '9. o, 4 ac) ' ocZ c , c o CO Y co W o � co, a a 0 , ZL. m o N O LOOS O oC fa 0� N C , �� O 0� N� , N, E 0 (O �' ' cOY L' 0 U• U'. p a) N' 0 N N N -p , -0, 00, �, Q' v, v; �� V'� @' o U -70. L; '�,; a Va}' �' U, aa> 0 p �, p. p a) b 0 {, Q o o, c, U' cO a, 01 a) )9, c. w < Y Y. 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E'. c. m 3, y 0 o' car 0' 2, 2, 2 m; -0 0 v -0 a0, 00, C 0' 0 c, E. m' a, 0 o m c 7, a), a). m, o, 0 c a; � D >; >, 5', On - 00 a a. os ' az U' cnUUU' U ¢ -; al-- o; mm, U, �; N; m; aowco0 W 0. O '- N M V (C) Co n co O) O ' N CO LO (O f� CO 0) 0 ,- N CO IC) O I's CO 0) EI ,— N CO (O CO I` CO CO .- .- N N N N N N N N N N CO CO CO CO CO M co cc) M co V 0 ;I (C) O ( a) CD O r O r O 0 0 N C O N CO NCO N 'p)•N On r4 M r O co H Or- O 0 c0 O r- O LLI (`a v E v v .-- o ; N 0 rn C7 E N •c C o • 1:0 Q J a CO U W £ d d IT_ Q w Q > Q oF 0 • Do, THE STATE A i:, x�, fl P l r 'n-PIE: X �� ir i , Vitt _ 1 _ 333 West Seventh Avenue Anchorage Alaska 99501-3572 GOVERNOR SEAN �,aRtit'LL g „ ',.-1-;--.r.'' ' Main. 907.279. 433 ® 4 ,ASIC FU Y. 90/.'27F,'./`x12: G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-146 ConocoPhillips Alaska, Inc. Permit No: 214-139 Surface Location: 310' FNL, 417.1' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 2047' FNL, 4271.4' FEL, SEC. 30, T11N, R11E, 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, L#,„i P 4,i,Ci-e- _ Cathy P. Yoerster � Chair DATED thisZ'rd1ay of October, 2014. • STATE OF ALASKA '41. I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILLpp, • 20 AAC 25.005 ^ ,V 15 - toil S J y 1 a.Type of Work: lb.Proposed Well Class: Development-Oil Q -. Service- Winj ❑ Single Zone El. 1 c.Specify if w Ili 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: Blanket J. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc • Bond No. 59-52-180• 1D-146 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16466' , TVD: 3784' . Kuparuk River Field I 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 310'FNL 417.1'FEL,Sec.23 Twn 11N Rng 10 E,UM ADL 25650,28248 t „23,Z1-6 West Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3802.7'FNL 1252.3'FEL,Sec.13 Twn 11N Rng 10E,UM ALK 468,591 01/02/7015 Total Depth: 9.Acres in Property: -T.ilv 14.Distance to Nearest Property: 2047'FNL 4271.4'FEL,Sec.30 Twn 11N Rng 11E,UM ,,li3i I `2540 5375 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): -dIb 10.KB Elevation above I 98.7 feet• 15.Distance to Nearest Well Open Surface: x-560672.6 y- 7. O1-846-23 Zone-4. GL Elevation above I 70.7 feet• to Same Pool: g0 ft 5959356.3`1 I 16.Deviated wells: Kickoff depth: 320 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90.96 degrees° Downhole: 1892 psi. Surface: 1467 psi 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# H40 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2708' 28' 28' 2708' 2356' 1275 sx Deep,205 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7806' 28' 28' 7806' 3836' 920 sx Class'0' 6.75" 4.5" 11.6# L-80 Hydril 563 8860' 7606' 3828' 16466' 3784' Slotted Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program L 20 AAC 25 050 requirements0 21. Verbal Approval: Commission Representative: Date(-0 '`�'--7✓) 22. I herebycertifythat the foregoing is true and correct. David Lee '263- 41 9 9 @ Contact david.l.leeAconocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature Phone 265-6120 Date (0 H k( (4. Commission Use Only Permit to Drill I API Number: Permit Approval �(S` See cover letter for other Number: p�I�_ /39 J0- 9-n 35 2 -0()-DO Date: I t 1 vl requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 5.21 Other: 3(J/9 1-e5 f 71-0 3jbD p5) • Samples req'd: Yes Nog Mud log req'd:Yes❑ No(r h 1, 7 v 1 a r_ rJ r -✓e✓+1-- r to 2 5'- f0 5 r re- asures: Yes VJ No❑ Directional svy req'd:Yes Erb-No❑ Spacing exception req'd: Yes❑ No ECJ Inclination-only svy req'd:Yes❑ No❑v' I 1 APPROVED BY ) Approved by: ./ COMMISSIONER THE COMMISSION Date:JO- 7.1---1 .- Form f ////���� �� J 10I2�1 y Submit Form and Form 10-401 IR1cI2G IJiJ A t's mit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate i v ()RV,- l°/231 -1 VC- /0/Z3/14 RECEIVED STATE OF ALASKA ALIRA OIL AND GAS CONSERVATION COMM ON SEP 1 7 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑✓ , Service- Winj ❑ Single Zone ❑✓ • lc.Specify if well is proposed for: Drill i]. Lateral ❑ Stratigraphic Test ❑ Development-Gas El Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 • 1D-146 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510 $360 MD: 16398'• TVD: 3784' . Kuparuk River Field 4a. Location of Well(Governmental Sect en): 7.Property Designation(Lease Number):X43 Surface: 327.6'FNL 419.8'FEL,Sec.23,wn 11N Rng 10 E,UM . ADL 25650,28248 1 a' 43 West Sak Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3813.4'FNL 1215.6'FEL,Sec.13 Twn 11N Rn.,10E,UM - ALK 468,591 2/1/2015 Total Depth: \ 9.Acres in Property: 14.Distance to Nearest Property: 2047'FNL 4271.4'FEL,Sec.30 Twn 11N Rng 11 'NUM , 891 neo 5375 ft 4b.Location of Well(State Base Plane Coordinates-•.,AD 27): 10.KB Elevation above I • 98.7 feet 15.Distance to Nearest Well Open Surface: x-560670 y- 5959338.5 Zone-4 - GL Elevation above I •70.7 feet to Same Pool: 90 ft 16.Deviated wells: Kickoff depth: 380 feet• 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 9r 96 degrees . Downhole: 1892 psi• Surface: 1467 psi • 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# H40 Welded :+' 28' 28' 108' 108' 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 27'.`' 28' 28' 2753' 2356' 1275 sx Deep,205 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7781\ 28' 28' 7780' 3836' 920 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 8618' 7580' 3828' 16398' 3784' Slotted Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be ,ompleted for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): ', Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural \, Surface Intermediate �\` Production Liner y1 Perforation Depth MD(ft): Perforation DeptI�TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ • Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch Ill Seabed Report El Drilling Fluid Program 7 _20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date /(,( . 15°b! l 22. I hereby certify that the foregoing is true and correct. �� � �®� David Lee @ 263-3741 r Contact david.l.lee(a conocophillips.com _._.__ Email Printed Name G.Alvord Title Alaska Drilling Manager Signature 4-(4- Phone 265-6120 \ Date 8(2-S12-0 ( Commission Use Only Permit to Dril II API Number: c Permit Approval See cover letter for other Number: l - /3� 50- OZ - ,236- ?.-00-00 Date: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: Bon t -s f fD 3.5-c,a , 5 i Samples req'd: Yes❑ NoVj \ Mud log req'd:Yes( _Nod vt•,i-i,v la r 71--C 5 f 1-c-, 2 SO O p 5 i H2S measures: Yes 121' No❑ Difectional svy req'd:Yes lr1 No Spacing exception req'd: Yes❑ Nog' Inclination-only svy req'd:Yes El No j SUPLRSLL ------------------ -_--a._...__. APPROVED BY Approved by: COOMI/I(5,$I N //�1THE COMMISSIO Date: QcR1 c '"� L ? 1l(y Submit Form and Form 10-401(Revised 10/2012) This permit is valid for2s fr t e date off{approval AAC 2,5.005(g)) Attachments in Duplicate Conoco? hiIIips RECEIVED SEP 1 7 2014 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 David Lee Phone (907) 263-3741 July 16, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1D-146 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the West Sak"D"sand. The expected spud date for 1D-146 is, February 1st 2015. The West Sak in the 1D area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1D-146 well will be drilled in the D Sand, up structure to the South with a planned lateral length of approximately 8660'. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 9.4 ppg equivalent during the drilling of this well. A FIT test to a minimum of 12.0 ppg will be performed after setting the surface casing and drilling out 20' of new formation, and a FIT test of 12.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1D-146. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely, 41,David Lee Kuparuk Drilling Engineer /ration for Permit to Drill,Well 1D-146 �r Revision No.0 Saved: 12-Aug-14 Permit It - West Sak Well #1D-146 Application for Permit to Drill Document • MaxWell P1 fx. ithiz $ VIII VgiI4e Table of Contents 1. Well Name 2 Requirements of 20 AA C 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (Ml VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 1D-146 PERMIT.doc Page 1 of 7 ORIGINAL Printed: 12-Aug-14 Dation for Permit to Drill,Well 1 D-146 Revision No.0 Saved: 12-Aug-14 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CemCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-146. 2. 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 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 327.6' FNL 419.8' FEL Sec. 23 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 98.7'AMSL Northings 5,959,338.5 Eastings:560,670.0 Pad Elevation 70.7'AMSL Location at Top of Productive Interval 3813.4' FNL 1215.6' FEL Sec. 13 Twn 11N Rng 10E UM (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7034' Northings: 5,961,170.1 Eastings:565,137.8 Total Vertical Depth, RKB: 3798' Total Vertical Depth, SS: 3699' Location at Total Depth 2047' FNL 4271.4' FEL Sec. 30 Twn 11N Rng 11E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 16398' Northings: 5,952,394.5 Eastings: 567,139.8 Total Vertical Depth, RKB: 3784' Total Vertical Depth, 55: 3685' 1D-146 PERMIT.doc Page 2 of 7 ORIGINAL Printed: 12-Aug-14 • tion for Permit to Drill,Well 1 D-146 Revision No.0 Saved: 12-Aug-14 and (D)other information required by 20 AAC 25.050(6); 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 1: Directional Plan 1D-146 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. 3. 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(ROPE)as required by 20 AAC 25.035,20 MC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stajk will be utilized to drill and complete well 1D-146. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 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 expected reservoir pressures in the West Sak sands in the 1D area are 0.489 psi/ft, or 9.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,467 psi, calculated thusly: MPSP = (3870 ft TVD)(0.489 - 0.11 psi/ft) = 1,467 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. /- and 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; Please see Attachment 2: 1D-146 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests 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(1); 1D-146 will be completed with a 7-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1D-146 PERMIT.doc Page u of-17 ORIGINAL Printed: 12-Aug-14 . tion for Permit to Drill,Well 1 D-146 Revision No.0 Saved: 12-Aug-14 5. 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 Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H40 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCREi"E Cemented to Surface with 10.75 13.5 45.5 L-80 Hydril 563 2753 28/ 28 2753/ 2356 1275 sx DeepCrete Lead, 205 sx DeepCRETE Tail Cement Top planned @ 4337' 7.625 9.875 29.7 L-80 Hydril 563 7780 28/ 28 7780/ 3836 MD/2850'TVD Cemented w/ 920 sx 15.8 ppg Class sG' 4.5 6.75 11.6 L-80 Hydril 563 8618 7580/ 3828 16398 / 3784 slotted-no cement slotted 6. 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); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the pliverter system used in the drilling of 1D-146 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1D-146 PERMIT.doc ORIGINALPrinted:P 2-Aug-14 • tion for Permit to Drill,Well 1D-146 Revision No.0 Saved: 12-Aug-14 7. 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; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilpiex AR) Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8 — 11.2 Lateral Mud Program (MI FazePro OBM) Intermediate Hole Mud Program (LSND) Value Density(ppg) 9.6 Fann 35 6 RPM 10,75"Csg Shoe to 7-5/8"Csg Point (lb/100 ft4-8 ,) Value HTHP Fluid Loss Density(ppg) 9.2 - 9.6 (mU30min) `5 Fann 35 6 RPM (Ib/100 ffz) 12 - 16 Drill Solids <5% API Filtrate Oil Water Ratio 70:30 (cc/30 min) <6 Electrical >400 pH 9.5 — 10.0 Stability(mV) Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) 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: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(t); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) 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: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10-146 PERMIT.doc Page u of-17 ORIGINAL Printed: 12-Aug-14 11) Illation for Permit to Drill,Well 1 D-146 Revision No.0 Saved: 12-Aug-14 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) 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: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) 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: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.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 also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16"x 24"insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13.5" hole to casing point at +/- 2753'MD/ 2356'ND as per directional plan. Run MWD tools as required for directional monitoring. csc.,vw�c.. toy °Al ,r y'si-Nn 4. Run and cement 10.75", 45.5#, L80, Hydril 563 casing to surface. 1Displace cement with mud and check floats upon bumping plug. Perform top job if required. 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 9.875" bit and 6.75"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. ( oiv _ f cky ot vub 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 12.0ppg EMW, recording results. 8. Directionally drill to 7-5/8"casing point at 7780' MD/ 3836'ND. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 7.625", 29.7# L80, Hydril 563 casing to surface. (top of cement to be 4337' MD/ 2850'ND which corresponds to 500'above the Ugnu C formation). 11. Install wellhead x 7.625" packoff and test to 3500 psi. 12. Flush 10.75"x 7.625"annulus with water, followed by diesel. 13. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. cscomu- ,f cy fL.Ss-r v,1-7 G .*J c1ok,hcb 14. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 12.0ppg EMW, recording results. 15. Directionally drill 6.75" hole to West Sak D Sand to TD at +/- 16398' MD/ 3784'ND as per directional plan. 10-146 PERMIT.doc Page 6 of 7 Printed: 12-Aug-14 ORIGINAL • tion for Permit to Drill,Well 1 D-146 Revision No.0 Saved: 12-Aug-14 16. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 17. PU and run 4-1/2"slotted liner. 18. Set liner hanger @ +/- 7580'MD/ 3828'TVD, set liner top packer. POOH. 19. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 20. Nipple down BOPE, nipple up tree and test. Pull BPV. 21. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 22. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) 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: (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.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1D-146 PERMIT.doc QRIGINALPage7of7 Printed: 12-Aug-14 • • .7aod D.S_ 1—D . t 1z : • • _ vl, i- i /l y A 1 D-1 46wp04 7 . 211 Plan Summary SURVEY PROGRAM ill \ epth From Depth To Survey/Plan Tool I o� 28.00 1200.00 1D-146wp04 (Plan: 1D-146) GYD-GC-SSI �j�'fi 1200.00 2710.00 1D-146wp04pPlan: 1D-146) MWD I )11i1�`,. \ 1200.00 2710.00 1D-146wp04(Plan: 1D-146) MWD+IFR-AK-CAZ-SC 2710.00 3700.00 1D-146wp04(Plan: 1D-146) MWD - /' �,! \ 2710.00 7805.87 1D-146wp04(Plan: 1D-146) MWD+IFR-AK-CAZ-SC ,, 7805.87 8805.00 1D-146wp04(Plan: 1D-146) MWD ���/1 ` \ 7805.87 16465.30 1D-146wp04(Plan: 1D-146) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size o 2355.70 2707.53 10-3/4"x13.5" 10-3/4 0° 3835.70 7805.87 7-5/8"x 9-7/8" 7-5/8i®to , o 3783.70 16465.30 4-1/2"x6-3/4" 4-1/2 8 I2II:o4-1/756-3/4° IP 4:,,,,.,mO G 4 o0 0 0 o° O %Do o rnoo c) V.ce n m mmm , 0 2000 4000 6000 er100. 11900(' 1y00(5' 12101110 Horizontal Departure 0 C r 16-190... . _.... .___- 330 30 er O ;� ':. n- 1100 60 '+ '\�' 1 ao - 300 ,.2r�A i.ao - noo .... na -,000 0 4 1 1 m-as U 30 A m n t - A1 i WOO E fii;t 270 ° 90 �' 3 � 12.1 1 - 4200 4200 4800 5000 MOO 5400 - MOO 5. U _ 240 ',a Alit yY 120 0 i i Tilt I I I I I It ii II I I II I I I I I I 1 I I I I I I 0200 - 11M1 0 2000 4000 6000 8000 10000 12000 14000 16000 210 15011200 - 12500 1ov - m. SECTION DETAILS 's'°0 - 1P°'s Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5959107.65 1700704.57 0.00 0.00 0.00 -1654.7 2 320.00 0.00 0.00 320.00 221.30 0.00 0.00 5959107.65 1700704.57 0.00 0.00 0.00 3 700.00 4.18 110.00 699.66 600.96 -4.74 13.02 5959103.02 1700717.63 1.10 110.00 13.64 Base Permafrost 4 1200.00 16.67 106.98 1190.44 1091.74 -32.03 99.06 5959076.42 1700803.90 2.50 -4.00 103.14 -1865.7 5 1700.00 25.05 84.30 1657.98 1559.28 -42.50 273.60 5959067.35 1700978.48 2.30 -55.00 276.82 6 2750.00 68.00 52.00 2372.24 2273.54 299.37 916.16 5959414.33 1701618.21 4.56 -41.94 850.25 t3 7 4500.00 68.00 52.00 3027.80 2929.10 1298.33 2194.76 5960423.42 1702888.64 0.00 0.00 1935.97 8 6205.00 68.00 87.00 3684.06 3585.36 1840.84 3645.79 5960977.51 1704335.12 1.90 96.74 3270.74 9 6604.63 86.42 89.38 3772.15 3673.45 1852.80 4033.61 5960992.57 1704722.80 4.65 7.48 3650.60 -2120.7 10 6609.82 86.42 89.38 3772.48 3673.78 1852.86 4038.79 5960992.67 1704727.98 0.00 0.00 3655.69 11 7805.87 88.00 145.00 3835.70 3737.00 1327.93 5059.73 5960476.00 1705753.00 4.65 89.97 4752.27 10-146 15May14 T1 MW 12 7825.87 88.00 145.00 3836.40 3737.70 1311.56 5071.20 5960459.72 1705764.59 0.00 0.00 4766.40 13 7981.34 88.78 148.81 3840.77 3742.07 1181.39 5156.03 5960330.25 1705850.47 2.50 78.52 4872.56 14 9303.08 88.78 148.81 3868.97 3770.27 50.96 5840.39 5959205.46 1706543.80 0.00 0.00 5742.81 15 9371.33 90.00 150.00 3869.70 3771.00 -7.78 5875.12 5959147.00 1706579.00 2.50 44.24 5787.22 1D-146 15May14 T2 MW 16 9569.62 90.46 154.94 3868.91 3770.21 -183.57 5966.75 5958971.98 1706672.03 2.50 84.69 5907.98 17 9906.95 90.46 154.94 3866.21 3767.51 -489.12 6109.65 5958667.61 1706817.36 0.00 0.00 6101.76 k15 18 10509.79 90.96 170.00 3858.70 3760.00 -1062.25 6290.71 5958096.00 1707003.00 2.50 88.01 6379.60 1D-146 15May14 T3 MW 19 10876.52 90.96 177.34 3852.56 3753.86 -1426.45 6331.13 5957732.17 1707046.33 2.00 89.96 6482.64 20 11261.04 90.96 177.34 3846.14 3747.44 -1810.50 6348.99 5957348.32 1707067.27 0.00 0.00 6566.92 21 11361.45 90.68 179.33 3844.70 3746.00 -1910.85 6351.91 5957248.00 1707071.00 2.00 97.77 6587.23 1D-146 15May14 T4 MW 22 16465.30 90.68 179.33 3783.70 3685.00 -7013.99 6411.98 5952146.00 1707172.00 0.00 0.00 7532.54 10-146 15May14 T5 MW Failed Anti-Collision. TCR required for wells -3136.7 ugc -3345.7 1D-41, 1C- 190 and 1C- 184. ugb -3478.7 -3519a .7 N 37V.op W Sak Surface Location Geodetic Datum: North American Datum 1983 Magneto Model: BGGM2013 TM Depth Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141 Magnetic Model Date: 22-Jan-14 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.62° North /Y: 59591 07.65 Ground Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.62°East - 415> East/X: 1700704.57 Rig: Doyon 141 NO GLOBAL FILTER:Using user defined selection&filtering criteria I ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-146 Plan: 1D-146 Plan: 1 D-146wp04 Plan Summary 30 September,2014 a 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit ND Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98,70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 10 Pad,KRU Site Position: Northing: 5,959,421.20 usft Latitude: 70°18'0.267 N From: Map Easting: 1,701,118.42 usft Longitude: 149°30'30.085 W Position Uncertainty: 0.00 usft Slot Radius: 36" Grid Convergence: 0.46° Well Plan:10-146 Well Position +N/-S 0.00 usft Northing: 5,959,107.65 usft Latitude: 70'17'57.215 N +E/-W 0.00 usft Easting: 1,700,704.57 usft Longitude: 149"30'42.224 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 70.70 usft Wellbore Plan:10-146 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) I°) (nT) BGGM2013 1/22/2014 19.62 80.91 57,615 Design 1D-146wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 100.00 9/30/2014 4 1899PM ,. COMPASS 50051 Build 61 I • 1 D-1 46wp04 Plan View 1500 z:/ is $�Q______ 1D-146 15May14 T1 MW 0 se 00 0 r. o 7-5/8"x 9-7/8" gQ00 ins" -"Poo -_ 1 D-146 15May14 T2 MW 0 o 1 000 0 10-3/4"x 13-1/2" 1D-146 15May14 T3 MW X1500 11000 1D-146 15May14 T4 MW 12000 0 000- 2 13000 1- 0 0 -4500— 14000 15000 1D-146 15May14 T5 MW -6000- 4-1/2"x6-3/4" 16000" 4:1-6465 1D-146wp04 I I I i I I I I I -3000 -1500 0 1500 3000 4500 6000 7500 9000 West(-)/East(+) (1500 usft/in) • • 1 D-1 46wp04 Section View 4 0- 0° 850- -E 50- - 1000 Z m 0 Lo t700- g0°op EL 2° a) 0 60 00 iiiN'` ,°o 0 1)-146wp04 0250- tea' o0 0 a) a 3 t= 10-3/4"x 13-1/2" o00 h 0 o 3400 co o 00 0 00 ° CO COrn o) O 83, 6 4250- 7-5/8"x 9-7/8" 0 0 0 ci0 0 0''� 4-1/2"x6-3/4" I I I I I I I I I I 0 850 1700 2550 3400 4250 5100 5950 6800 7650 Vertical Section at 100.00°(850 usft/in) 110 111 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit + �* ND Reference: Plan:(70.70+28)@98.7 @ 98.70usf(Doyon 141) f. lilt„rS t((.°: �kY a't� Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usN(Doyon 141) Well: Plan:1D-146 T r.o' Jahr% triF•iiclUTPi. North Reference: True Wellbore: Plan:1 D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Survey Tool Program Date 9/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,200.00 1D-146wp04(Plan:10-146) GYD-GC-SS Gyrodata gyro single shots 1200.00 2,710.00 1 D-146wp04(Plan:1D-146) MWD MWD-Standard 1200.00 2,710.00 1 D-146wp04(Plan:1D-146) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,710.00 3,700.00 1D-146wp04(Plan:1D-146) MWD MWD-Standard 2,710.00 7,805.87 1D-146wp04(Plan:10-146) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,805.87 8,805.00 1D-146wp04(Plan:1D-146) MWD MWD-Standard 7,805.87 16,465.30 1D-146wp04(Plan:1D-146) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (') (°) (usft) (u sit) (°/100usft) (°) (usft) (usft) (usft) (usft) 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 5,959,107.65 1,700,704.57 0.00 0.00 100.00 0.00 0.00 100.00 1.30 0.00 0.00 5,959,107.65 1,700,704.57 0.05 1.15 200.00 0.00 0.00 200.00 101.30 0.00 0.00 5,959,107.65 1,700,704.57 0.20 1.15 300.00 0.00 0.00 300.00 201.30 0.00 0.00 5,959,107.65 1,700,704.57 0.34 1.15 • 320.00 0.00 0.00 320.00 221.30 0.00 0.00 5,959,107.65 1,700,704.57 0.37 1.15 Start Build 1.10 400.00 0.88 110.00 400.00 301.30 1.10 110.00 5,959,107.44 1,700,705.15 0.45 1.15 500.00 1.98 110.00 499.96 401.26 1.10 0.00 5,959,106.61 1,700,707.50 0.54 1.15 600.00 3.08 110.00 599.87 501.17 1.10 0.00 5,959,105.13 1,700,711.66 0.64 1.16 700.00 4.18 110.00 699.66 600.96 1.10 0.00 5,959,103.02 1,700,717.63 0.76 1.16 Start DLS 2.50 TFO-4.00 800.00 6.68 108.50 799.21 700.51 2.50 -4.00 5,959,100.00 1,700,726.59 0.90 1.16 900.00 9.17 107.81 898.24 799.54 2.50 -2.51 5,959,095.82 1,700,739.73 1.04 1.16 1,000.00 11.67 107.42 996.59 897.89 2.50 -1.83 5,959,090.49 1,700,757.01 1.20 1.16 1,100.00 14.17 107.16 1,094.04 995.34 2.50 -1.44 5,959,084.02 1,700,778.42 1.38 1.16 1,200.00 16.67 106.98 1,190.44 1,091.74 2.50 -1.19 5,959,076.42 1,700,803.90 1.57 1.15 Start DLS 2.30 TFO-55.00 1,300.00 18.09 100.91 1,285.88 1,187.18 2.30 -55.00 5,959,069.52 1,700,832.92 1.69 1.15 9/302014 4:18:39PM Page 3 COMPASS 5000.1 Build 61 • • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) . (soft) (soft) (soft) (soft) 1,400.00 19.66 95.73 1,380.50 1,281.80 2.30 -49.20 5,959,065.17 1,700,864.94 1.83 1.15 1,500.00 21.37 91.31 1,474.16 1,375.46 2.30 -44.30 5,959,063.35 1,700,899.91 2.11 1.15 1,600.00 23.17 87.54 1,566.70 1,468.00 2.30 -40.16 5,959,064.08 1,700,937.78 2.52 1.16 1,696.38 24.98 84.41 1,654.70 1,556.00 2.30 -36.67 5,959,067.19 1,700,976.96 3.02 1.17 Base Permafrost 1,700.00 25.05 84.30 1,657.98 1,559.28 2.30 -33.81 5,959,067.35 1,700,978.48 3.02 1.17 Start DLS 4.56 TFO-41.94 1,800.00 28.59 77.93 1,747.22 1,648.52 4.56 -41.94 5,959,074.82 1,701,022.91 3.59 1.18 1,900.00 32.37 72.90 1,833.40 1,734.70 4.56 -36.25 5,959,088.10 1,701,071.81 4.26 1.19 1,938.57 33.87 71.23 1,865.70 1,767.00 4.56 -31.91 5,959,094.75 1,701,091.80 5.02 1.22 t3 2,000.00 36.31 68.83 1,915.97 1,817.27 4.56 -30.52 5,959,107.10 1,701,124.87 5.02 1.22 2,100.00 40.36 65.47 1,994.40 1,895.70 4.56 -28.55 5,959,131.70 1,701,181.77 5.89 1.28 2,200.00 44.50 62.63 2,068.20 1,969.50 4.56 -25.91 5,959,161.75 1,701,242.13 6.85 1.36 2,275.69 47.67 60.75 2,120.70 2,022.00 4.56 -23.82 5,959,188.01 1,701,289.90 7.90 1.47 k15 2,300.00 48.69 60.18 2,136.91 2,038.21 4.56 -22.51 5,959,197.07 1,701,305.58 7.90 1.47 2,400.00 52.93 58.03 2,200.09 2,101.39 4.56 -22.13 5,959,237.41 1,701,371.72 9.02 1.63 2,500.00 57.21 56.11 2,257.33 2,158.63 4.56 -20.77 5,959,282.54 1,701,440.13 10.22 1.82 2,600.00 61.51 5437 2,308.29 2,209.59 4.56 -19.67 5,959,332.16 1,701,510.37 11.48 2.04 2,700.00 65.83 52.76 2,352.64 2,253.94 4.56 -18.78 5,959,385.97 1,701,582.01 12.78 2.30 2,707.53 66.16 52.65 2,355.70 2,257.00 4.56 -18.07 5,959,390.18 1,701,587.45 5.52 1.42 10-314"x 13.112" 2,750.00 68.00 52.00 2,372.24 2,273.54 4.56 -18.02 5,959,414.33 1,701,618.21 5.52 1.42 Start 1750.00 hold at 2750.00 MD 2,800.00 68.00 52.00 2,390.97 2,292.27 0.00 0.00 5,959,443.17 1,701,654.51 5.87 1.43 2,900.00 68.00 52.00 2,428.43 2,329.73 0.00 0.00 5,959,500.83 1,701,727.10 6.75 1.52 3,000.00 68.00 52.00 2,465.89 2,367.19 0.00 0.00 5,959,558.49 1,701,799.70 7.80 1.66 9/302014 4:18:39PM Page 4 COMPASS 5000.1 Build 61 ! 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit ND Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Veit.Error (usft) (°) (") (usft) (usft) (°l100usft) (1 (usft) (usft) (usft) (usft) 3,100.00 68.00 52.00 2,503.35 2.404.65 0.00 0.00 5,959,616.15 1,701,872.30 8.97 1.85 3,200.00 68.00 52.00 2,540.81 2,442.11 0.00 0.00 5,959,673.81 1,701,944.89 10.21 2.07 3,300.00 68.00 52.00 2,578.27 2,479.57 0.00 0.00 5,959,731.48 1,702,017.49 11.50 2.32 3,400.00 68.00 52.00 2,615.73 2,517.03 0.00 0.00 5,959,789.14 1,702,090.08 12.82 2.58 3,500.00 68.00 52.00 2,653.19 2,554.49 0.00 0.00 5,959,846.80 1,702,162.68 14.17 2.85 3,600.00 68.00 52.00 2,690.65 2,591.95 0.00 0.00 5,959,904.46 1,702,235.27 15.54 3.13 3,700.00 68.00 52.00 2,728.11 2,629.41 0.00 0.00 5,959,962.12 1,702,307.87 16.93 3.42 3,800.00 68.00 52.00 2,765.58 2,666.88 0.00 0.00 5,960,019.78 1,702,380.47 9.14 224 • 3,900.00 68.00 52.00 2,803.04 2,704.34 0.00 0.00 5,960,077.45 1,702,453.06 9.61 2.37 4,000.00 68.00 52.00 2,840.50 2,741.80 0.00 0.00 5,960,135.11 1,702,525.66 10.08 2.50 4,100.00 68.00 52.00 2,877.96 2,779.26 0.00 0.00 5,960,192.77 1,702,598.25 10.57 2.64 4,200.00 68.00 52.00 2,915.42 2,816.72 0.00 0.00 5,960,250.43 1,702,670.85 11.06 2.77 4,300.00 68.00 52.00 2,952.88 2,854.18 0.00 0.00 5,960,308.09 1,702,743.44 11.56 2.91 4,400.00 68.00 52.00 2,990.34 2,891.64 0.00 0.00 5,960,365.76 1,702,816.04 12.06 3.05 4,500.00 68.00 52.00 3,027.80 2,929.10 0.00 0.00 5,960,423.42 1,702,888.64 12.57 3.20 Start DLS 1.90 TFO 96.74 4,600.00 67.79 54.04 3,065.43 2,966.73 1.90 96.74 5,960,479.74 1,702,962.19 13.00 3.34 4,700.00 67.61 56.08 3,103.39 3,004.69 1.90 95.97 5,960,533.32 1,703,037.59 13.33 3.49 4,792.39 67.46 57.97 3,138.70 3,040.00 1.90 95.19 5,960,580.36 1,703,108.82 13.66 3.63 ugc 4,800.00 67.45 58.13 3,141.62 3,042.92 1.90 94.47 5,960,584.12 1,703,114.76 13.66 3.63 4,900.00 67.31 60.18 3,180.08 3,081.38 1.90 94.41 5,960,632.08 1,703,193.61 13.99 3.78 5,000.00 67.21 62.24 3,218.74 3,120.04 1.90 93.62 5,960,677.14 1,703,274.06 14.33 3.92 5,100.00 67.13 64.29 3,257.55 3,158.85 1.90 92.83 5,960,719.25 1,703,356.02 14.66 4.07 5,200.00 67.07 66.36 3,296.47 3,197.77 1.90 92.03 5,960,758.37 1,703,439.41 14.99 4.22 5,300.00 67.04 68.42 3,335.45 3,236.75 1.90 91.23 5,960,794.46 1,703,524.12 15.31 4.37 9/302014 4:18:39PM Page 5 COMPASS 5000.1 Build 61 • , Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit ND Reference: Plan:(70.70+28) 98.7(4)98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)(4)98.7 Q 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (") (usft) (usft) (usft) (usft) 5,326.27 67.04 68.96 3.345.70 3,247.00 1.90 90.42 5,960,803.43 1,703,546.58 15.63 4.52 ugb 5,400.00 67.04 70.48 3,374.46 3,275.76 1.90 90.21 5,960,827.47 1,703,610.06 15.63 4.52 5,500.00 67.07 72.54 3,413.44 3,314.74 1.90 89.62 5,960,857.37 1,703,697.14 15.94 4.67 5,600.00 67.12 74.60 3,452.37 3,353.67 1.90 88.81 5,960,884.12 1,703,785.27 16.25 4.82 5,667.80 67.17 76.00 3,478.70 3,380.00 1.90 88.01 5,960,900.46 1,703,845.57 16.54 4.97 uga 5,700.00 67.20 76.66 3,491.18 3,392.48 1.90 87.47 5,960,907.70 1,703,874.35 16.54 4.97 5,800.00 67.31 78.72 3,529.85 3,431.15 1.90 87.21 5,960,928.09 1,703,964.28 16.82 5.12 5,900.00 67.44 80.77 3,568.33 3,469.63 1.90 86.42 5,960,945.25 1,704,054.95 17.10 5.27 5,924.45 67.47 81.27 3,577.70 3,479.00 1.90 85.63 5,960,948.95 1,704,077.23 17.36 5.42 N 6,000.00 67.60 82.82 3,606.57 3,507.87 1.90 85.44 5,960,959.16 1,704,146.28 17.36 5.42 6,100.00 67.78 84.86 3,644.54 3,545.84 1.90 84.84 5,960,969.83 1,704,238.17 17.60 5.58 6,200.00 67.99 86.90 3,682.19 3,583.49 1.90 84.07 5,960,977.22 1,704,330.50 17.84 5.73 6,205.00 68.00 87.00 3,684.06 3,585.36 1.90 83.30 5,960,977.51 1,704,335.12 17.85 5.74 Start DLS 4.65 TFO 7.48 6,300.00 72.38 87.60 3,716.25 3,617.55 4.65 7.48 5,960,982.42 1,704,424.34 18.26 5.89 6,400.00 76.99 88.21 3,742.66 3,643.96 4.65 7.28 5,960,986.72 1,704,52065 18.72 6.04 6,500.00 81.60 88.79 3,761.24 3,662.54 4.65 7.12 5,960,990.08 1,704,618.82 19.18 6.21 6,600.00 86.21 89.35 3,771.86 3,673.16 4.65 7.01 5,960,992.48 1,704,718.18 19.62 6.38 6,604.63 86.42 89.38 3,772.15 3,673.45 4.65 6.95 5,960,992.57 1,704,722.80 19.64 6.39 Start 5.19 hold at 6604.63 MD 6,609.82 86.42 89.38 3,772.48 3,673.78 0.00 0.00 5,960,992.67 1,704,727.98 19.67 6.39 • Start DLS 4.65 TFO 89.97 6,700.00 86.43 93.58 3,778.10 3,679.40 465 89.97 5,960,991.07 1,704,817.94 19.45 6.55 6,800.00 86.47 98.23 3,784.29 3,685.59 465 89.71 5,960,981.60 1,704,917.26 19.10 6.72 6,900.00 86.53 102.89 3,790.40 3,691.70 465 89.42 5,960,964.10 1,705,015.49 18.63 6.89 9/30/1014 4:18:39PM Page 6 COMPASS 5000.1 Build 61 • i Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)/ 98.7/98.70usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Planned Survey • MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) (usft) 7,000.00 86.61 107.54 3,796.39 3,697.69 4.65 89.14 5,960,938.69 1,705,111.99 18.03 7.06 7,022.17 86.63 108.57 3,797.70 3,699.00 4.65 88.86 5,960,932.00 1,705,133.08 17.33 7.23 Top W Sak 7,100.00 86.71 112.19 3,802.22 3,703.52 4.65 88.80 5,960,905.53 1,705,206.11 17.33 7.23 7,200.00 86.84 116.85 3,807.85 3,709.15 4.65 88.59 5,960,864.84 1,705,297.24 16.52 7.40 7,300.00 86.98 121.50 3,813.24 3,714.54 4.65 88.33 5,960,816.89 1,705,384.79 15.61 7.58 7,400.00 87.15 126.15 3,818.37 3,719.67 4.65 88.08 5,960,761.99 1,705,468.17 14.61 7.75 7,500.00 87.33 130.79 3,823.18 3,724.48 4.65 87.84 5,960,700.50 1,705,546.84 13.54 7.92 7,600.00 87.53 135.44 3,827.66 3,728.96 4.65 87.61 5,960,632.83 1,705,620.28 12.42 8.09 7,700.00 87.75 140.08 3,831.77 3,733.07 4.65 87.41 5,960,559.43 1,705,688.01 11.27 8.27 7,800.00 87.99 144.73 3,835.49 3,736.79 4.65 87.22 5,960,480.77 1,705,749.59 10.12 8.44 7,805.87 88.00 145.00 3,835.70 3,737.00 4.65 87.04 5,960,476.00 1,705,753.00 10.05 8.45 Start 20.00 hold at 7805.87 MD-7-5/8"x 9-7/8" 7,825.87 88.00 145.00 3,836.40 3,737.70 0.00 0.00 5,960,459.72 1,705,764.59 10.16 8.46 Start DLS 2.50 TFO 78.52 7,900.00 88.37 146.82 3,838.75 3,740.05 2.50 78.52 5,960,398.70 1,705,806.61 10.09 8.47 7,981.34 88.78 148.81 3,840.77 3,742.07 2.50 78.46 5,960,330.25 1,705,850.47 10.12 8.48 Start 1321.74 hold at 7981.34 MD 8,000.00 88.78 148.81 3,841.17 3,742.47 0.00 0.00 5,960,314.37 1,705,860.26 10.30 8.49 8,100.00 88.78 148.81 3,843.30 3,744.60 0.00 0.00 5,960,229.27 1,705,912.71 11.35 8.53 8,200.00 88.78 148.81 3,845.44 3,746.74 0.00 0.00 5,960,144.17 1,705,965.17 12.52 8.58 8,300.00 88.78 148.81 3,847.57 3,748.87 0.00 0.00 5,960,059.07 1,706,017.63 13.78 8.65 8,400.00 88.78 148.81 3,849.70 3,751.00 0.00 0.00 5,959,973.97 1,706,070.08 15.11 8.73 8,500.00 88.78 148.81 3,851.84 3,753.14 0.00 0.00 5,959,888.87 1,706,122.54 16.50 8.83 8,600.00 88.78 148.81 3,853.97 3,755.27 0.00 0.00 5,959,803.77 1,706,174.99 17.92 8.94 8,700.00 88.78 148.81 3,856.10 3,757.40 0.00 0.00 5,959,718.67 1,706,227.45 19.38 9.06 8,800.00 88.78 148.81 3,858.24 3,759.54 0.00 0.00 5,959,633.57 1,706,279.91 20.86 9.20 9/302014 4:18.'39PM Page 7 COMPASS 5000 1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) p) (°) (usft) (usft) (1l100usft) (°) (usft) (usft) (usft) (usft) 8,900.00 88.78 148.81 3,860.37 3,761.67 0.00 0.00 5,959,548.47 1,706,332.36 12.26 8.68 9,000.00 88.78 148.81 3,862.51 3,763.81 0.00 0.00 5,959,463.37 1,706,384.82 12.69 8.72 9,100.00 88.78 148.81 3,864.84 3,765.94 0.00 0.00 5,959,378.27 1,706,437.27 13.14 8.77 9,200.00 88.78 148.81 3,866.77 3,768.07 0.00 0.00 5,959,293.17 1,706,489.73 13.59 8.82 9,300.00 88.78 148.81 3,868.91 3,770.21 0.00 0.00 5,959,208.08 1,706,542.19 14.05 8.87 9,303.08 88.78 148.81 3,868.97 3,770.27 0.00 0.00 5,959,205.46 1,706,543.80 14.07 8.87 Start DLS 2.50 TFO 44.24 9,371.33 90.00 150.00 3,869.70 3,771.00 2.50 44.24 5,959,147.00 1,706,579.00 14.01 8.91 Start DLS 2.50 TFO 84.69 9,400.00 90.07 150.71 3,869.68 3,770.98 2.50 84.69 5,959,122.20 1,706,593.38 13.91 8.93 9,500.00 90.30 153.20 3,869.37 3,770.67 2.50 84.69 5,959,034.33 1,706,641.09 13.57 8.98 9,569.62 90.46 154.94 3,868.91 3,770.21 2.50 84.69 5,958,971.98 1,706,672.03 13.36 9.03 Start 331.33 hold at 9669.62 MD 9,600.00 90.46 154.94 3,868.66 3,769.96 0.00 0.00 5,958,944.57 1,706,685.12 13.50 9.05 9,700.00 90.46 154.94 3,867.86 3,769.16 0.00 0.00 5,958,854.34 1,706,728.20 14.00 9.11 9,800.00 90.46 154.94 3,867.06 3,768.36 0.00 0.00 5,958,764.11 1,706,771.28 14.51 9.18 9,900.00 90.46 154.94 3,866.26 3,767.56 0.00 0.00 5,958,673.88 1,706,814.37 15.02 9.25 9,906.95 90.46 154.94 3,866.21 3,767.51 0.00 0.00 5,958,667.61 1,706,817.36 15.05 9.25 Start DLS 2.50 TFO 88.01 10,000.00 90.54 157.26 3,865.40 3,766.70 2.50 88.01 5,958,582.86 1,706,855.73 14.85 9.32 10,100.00 90.62 159.76 3,864.38 3,765.68 2.50 88.03 5,958,490.13 1,706,893.11 14.61 9.40 10,200.00 90.71 162.26 3,863.22 3,784.52 2.50 88.06 5,958,395.86 1,706,926.40 14.41 9.48 10,300.00 90.79 164.76 3,861.91 3,763.21 2.50 88.09 5,958,300.23 1,706,955.55 14.25 9.56 10,400.00 90.87 167.26 3,860.46 3,761.76 2.50 88.12 5,958,203.42 1,706,980.50 14.12 9.65 10,500.00 90.95 169.76 3,858.86 3,760.16 2.50 88.15 5,958,105.62 1,707,001.20 14.04 9.73 10,509.79 90.96 170.00 3,858.70 3,760.00 2.50 88.19 5,958,096.00 1,707,003.00 14.04 9.74 Start DLS 2.00 TFO 89.96 10,600.00 90.96 171.80 3,857.19 3,758.49 2.00 89.96 5,958,007.06 1,707,017.97 14.08 9.82 9/302014 4:18:39PM Page 8 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (") (°) (usft) (usft) (°1100usft) (^) (usft) (usft) (usft) (usft) 10,700.00 90.96 173.80 3,855.51 3,756.81 2.00 90.00 5,957,907.98 1,707,031.29 14.15 9.92 10,800.00 90.96 175.81 3,853.84 3,755.14 2.00 90.03 5,957,808.50 1,707,041.14 14.25 10.01 10,876.52 90.96 177.34 3,852.56 3,753.86 2.00 90.06 5,957,732.17 1,707,046.33 14.34 10.08 Start 384.52 hold at 10876.52 MD 10,900.00 90.96 177.34 3,852.17 3,753.47 0.00 0.00 5,957,708.74 1,707,047.61 14.44 10.11 11,000.00 90.96 177.34 3,850.50 3,751.80 0.00 0.00 5,957,608.91 1,707,053.05 14.86 10.21 11,100.00 90.96 177.34 3,848.83 3,750.13 0.00 0.00 5,957,509.08 1,707,058.50 15.29 10.31 11,200.00 90.96 177.34 3,847.16 3,748.46 0.00 0.00 5,957,409.25 1,707,063.95 15.73 10.41 11,261.04 90.96 177.34 3,846.14 3,747.44 0.00 0.00 5,957,348.32 1,707,067.27 16.00 10.47 Start DLS 2.00 TFO 97.77 11,300.00 90.85 178.11 3,845.52 3,746.82 2.00 97.77 5,957,309.41 1,707,069.13 16.04 10.52 11,361.45 90.68 179.33 3,844.70 3,746.00 2.00 97.78 5,957,248.00 1,707,071.00 16.09 10.58 Start 5103.85 hold at 11361.45 MD 11,400.00 90.68 179.33 3,844.24 3,745.54 0.00 0.00 5,957,209.47 1,707,071.76 16.24 10.62 11,500.00 90.68 179.33 3,843.04 3,744.34 0.00 0.00 5,957,109.50 1,707,073.74 16.68 10.73 11,600.00 90.68 179.33 3,841.85 3,743.15 0.00 0.00 5,957,009.54 1,707,075.72 17.12 10.84 11,700.00 90.68 179.33 3,840.65 3,741.95 0.00 0.00 5,956,909.57 1,707,077.70 17.58 10.96 11,800.00 90.68 179.33 3,839.46 3,740.76 0.00 0.00 5,956,809.61 1,707,079.68 18.04 11.07 11,900.00 90.68 179.33 3,838.26 3,739.56 0.00 0.00 5,956,709.65 1,707,081.66 18.51 11.19 12,000.00 90.68 179.33 3,837.07 3,738.37 0.00 0.00 5,956,609.68 1,707,083.64 18.99 11.31 12,100.00 90.68 179.33 3,835.87 3,737.17 0.00 0.00 5,956,509.72 1,707,085.62 19.47 11.43 12,200.00 90.68 179.33 3,834.68 3,735.98 0.00 0.00 5,956,409.76 1,707,087.59 19.95 11.55 12,300.00 90.68 179.33 3,833.48 3,734.78 0.00 0.00 5,956,309.79 1,707,089.57 20.45 11.67 12,400.00 90.68 179.33 3,832.29 3,733.59 0.00 0.00 5,956,209.83 1,707,091.55 20.94 11.79 12,500.00 90.68 179.33 3,831.09 3,732.39 0.00 0.00 5,956,109.86 1,707,093.53 21.44 11.92 12,600.00 90.68 179.33 3,829.90 3,731.20 0.00 0.00 5,956,009.90 1,707,095.51 21.95 12.05 12,700.00 90.68 179.33 3,828.70 3,730.00 0.00 0.00 5,955,909.94 1,707,097.49 22.46 12.17 913012014 4:18:39PM Page 9 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:10-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146wp04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (1 (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 12,800.00 90.68 179.33 3827.51 3,728.81 0.00 0.00 5,955,809.97 1,707,099.47 22.97 12.30 12,900.00 90.68 179.33 3,826.31 3,727.61 0.00 0.00 5,955,710.01 1,707,101.45 23.48 12.43 13,000.00 90.68 179.33 3,825.12 3,726.42 0.00 0.00 5,955,610.05 1,707,103.43 24.00 12.57 13,100.00 90.68 179.33 3,823.92 3,725.22 0.00 0.00 5,955,510.08 1,707,105.40 24.52 12.70 13,200.00 90.68 179.33 3,822.73 3,724.03 0.00 0.00 5,955,410.12 1,707,107.38 25.04 12.83 13,300.00 90.68 179.33 3,821.53 3,722.83 0.00 0.00 5,955,310.16 1,707,109.36 25.57 12.97 13,400.00 90.68 179.33 3,820.34 3,721.64 0.00 0.00 5,955,210.19 1,707,111.34 26.10 13.10 13,500.00 90.68 179.33 3,819.14 3,720.44 0.00 0.00 5,955,110.23 1,707,113.32 26.63 13.24 13,600.00 90.68 179.33 3,817.95 3,719.25 0.00 0.00 5,955,010.26 1,707,115.30 27.16 13.38 13,700.00 90.68 179.33 3,816.75 3,718.05 0.00 0.00 5,954,910.30 1,707,117.28 27.70 13.52 13,800.00 90.68 179.33 3,815.56 3,716.86 0.00 0.00 5,954,810.34 1,707,119.26 28.23 13.66 13,900.00 90.68 179.33 3,814.36 3,715.66 0.00 0.00 5,954,710.37 1,707,121.24 28.77 13.80 14,000.00 90.68 179.33 3,813.16 3,714.46 0.00 0.00 5,954,610.41 1,707,123.21 29.31 13.94 14,100.00 90.68 179.33 3,811.97 3,713.27 0.00 0.00 5,954,510.45 1,707,125.19 29.85 14.09 14,200.00 90.68 179.33 3,810.77 3,712.07 0.00 0.00 5,954,410.48 1,707,127.17 30.40 14.23 14,300.00 90.68 179.33 3,809.58 3,710.88 0.00 0.00 5,954,310.52 1,707,129.15 30.94 14.37 14,400.00 90.68 179.33 3,808.38 3,709.68 0.00 0.00 5,954,210.55 1,707,131.13 31.49 14.52 14,500.00 90.68 179.33 3,807.19 3,708.49 0.00 0.00 5,954,110.59 1,707,133.11 32.03 14.67 14,600.00 90.68 179.33 3,805.99 3,707.29 0.00 0.00 5,954,010.63 1,707,135.09 32.58 14.81 14,700.00 90.68 179.33 3,804.80 3,706.10 0.00 0.00 5,953,910.66 1,707,137.07 33.13 14.96 14,800.00 90.68 179.33 3,803.60 3,704.90 0.00 0.00 5,953,810.70 1,707,139.05 33.68 15.11 14,900.00 90.68 179.33 3,802.41 3,703.71 0.00 0.00 5,953,710.74 1,707,141.02 34.23 15.26 15,000.00 90.68 179.33 3,801.21 3,702.51 0.00 0.00 5,953,610.77 1,707,143.00 34.79 15.41 15,100.00 90.68 179.33 3,800.02 3,701.32 0.00 0.00 5,953,510.81 1,707,144.98 35.34 15.56 15,200.00 90.68 179.33 3,798.82 3,700.12 0.00 0.00 5,953,410.85 1,707,146.96 35.89 15.71 15,300.00 90.68 179.33 3,797.63 3,698.93 0.00 0.00 5,953,310.88 1,707,148.94 36.45 15.86 15,400.00 90.68 179.33 3,796.43 3,697.73 0.00 0.00 5,953,210.92 1,707,150.92 37.01 16.01 9/302014 4•18:39PM Page 10 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kupt Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit ND Reference: Plan:(70.704-28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.704-28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146vep04 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°l l l (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 15,500.00 90.68 179.33 3,795.24 3,696.54 0.00 0.00 5,953,110.95 1,707,152.90 37.56 16.16 15,600.00 90.68 179.33 3,794.04 3,695.34 0.00 0.00 5,953,010.99 1,707,154.88 38.12 16.32 15,700.00 90.68 179.33 3,792.85 3,694.15 0.00 0.00 5,952,911.03 1,707,156.86 38.68 16.47 15,800.00 90.68 179.33 3,791.65 3,692.95 0.00 0.00 5,952,811.06 1,707,158.83 39.24 16.62 15,900.00 90.68 179.33 3,790.46 3,691.76 0.00 0.00 5,952,711.10 1,707,160.81 39.80 16.78 16,000.00 90.68 179.33 3,789.26 3,690.56 0.00 0.00 5,952,611.14 1,707,162.79 40.36 16.93 16,100.00 90.68 179.33 3,788.07 3,689.37 0.00 0.00 5,952,511.17 1,707,164.77 40.92 17.09 16,200.00 90.68 179.33 3,786.87 3,688.17 0.00 0.00 5,952,411.21 1,707,166.75 41.48 17.24 16,300.00 90.68 179.33 3,785.68 3,686.98 0.00 0.00 5,952,311.24 1,707,168.73 42.04 17.40 16,400,00 90.68 179.33 3,784.48 3,685.78 0.00 0.00 5,952,211.28 1,707,170.71 42.60 17.56 16,465.30 90.68 179.33 3,783.70 3,685.00 0.00 0.00 5,952,146.00 1,707,172.00 42.97 17.66 TD at 16465.30-4-112'x6.314" 9/30/2014 4:18 39PM Page 11 COMPASS 5000 1 Build 61 1110 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) ate_ ',: (usft) (usft) ft �: (us ) (usft) Latitude Longitude 10-146 15May14 T5 MV 0.00 0.00 3,783.70 -7,013.99 6,411.98 5,952,146.00 1,707,172.00 70°16'48.204 N 149°27'35.469 W -plan hits target center -Circle(radius 100.00) 1D-146 15May14 T4 MV 0.00 0.00 3,844.70 -1,910.85 6,351.91 5,957,248.00 1,707,071.00 70°17'38.395 N 149°27'37.093 W -plan hits target center -Circle(radius 100.00) 1D-146 15May14 T3 MV 0.00 0.00 3,858.70 -1,062.25 6,290.71 5,958,096.00 1,707,003.00 70°17'46.742 N 149°27'38.856 W -plan hits target center -Circle(radius 100.00) 1D-146 15May14 T1 MV 0.00 0.00 3,835.70 1,327.93 5,059.73 5,960,476.00 1,705,753.00 70°18'10.259 N 149°28'14.691 W -plan hits target center -Circle(radius 100.00) 10-146 15May14 T2 MV 0.00 0.00 3,869.70 -7.78 5,875.12 5,959,147.00 1,706,579.00 70°17'57.116 N 149°27'50.946 W -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter • (usft( (usft) Name (") 11 7,805.87 3,835.70 7-5/8"x 9-7/8" 7-5/8 9-7/8 16,465.30 3,783.70 4-1/2"x6-3/4" 4-1/2 6-3/4 2,707.53 2,355.70 10-3/4"x 13-1/2" 10-3/4 13-1/2 9/30/2014 4:18.39PM Page 12 COMPASS 5000 1 Build 61 ! 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70usd(Doyon 141) Well: Plan.1D-146 North Reference: True Wellbore: Plan 1D-146 Survey Calculation Method: Minimum Curvature Design: 1 D-146wp04 Database: EDM Alaska Prod Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name ��s �n. : Litholo9Y (1 O 1,938.57 1,865.70 t3 0.00 2,275.69 2,120.70 k15 0.00 1,696.38 1,654.70 Base Permafrost 0.00 4,792.39 3,138.70 ugc 0.00 5,924.45 3,577.70 N 0.00 7,022.17 3,797.70 Top W Sak 0.00 5,667.80 3,478.70 uga 0.00 5,326.27 3,345.70 ugb 0.00 9/30/1014 4:18:39PM Page 13 COMPASS 5000.1 Build 61 ! • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1 D-146 Project: Kuparuk River Unit TVD Reference: Plan:(70.70+28)@98.7 @ 98.70usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:(70.70+28)@98.7 @ 98.70ustt(Doyon 141) Well: Plan:1D-146 North Reference: True Wellbore: Plan:1D-146 Survey Calculation Method: Minimum Curvature Design: 1D-146wp04 Database: EDM Alaska Prod Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +El-W Non) (usft) a (usft) (usft) Comment 320.00 320.00 0.00 0.00 Start Build 1.10 700.00 699.66 -4.74 13.02 Start DLS 2.50 TFO-4.00 1200.00 1,190.44 -32.03 99.08 Start DLS 2.30 TFO-55.00 1200.00 1,657.98 -42.50 273.60 Start DLS 4.56 TFO-41.94 2,750.00 2,372.24 299.37 916.16 Start 1750.00 hold at 2750.00 MD 4500.00 3,027.80 1,298.33 2,194.76 Start DLS 1.90 TFO 96.74 6,205.00 3,684.06 1,840.84 3645.79 Start DLS 465 TFO 7.48 6,604.63 3,772.15 1652.80 4,033.61 Start 5.19 hold at 6604.63 MD 6,609.82 3,772.48 1,852.86 4,038.79 Start DLS 4.65 TFO 89.97 7,805.87 3,835.70 1,327.93 5,059.73 Start 20.00 hold at 7805.87 MD 7,825.87 3,836.40 1,311.56 5,071.20 Start DLS 2.50 TFO 78.52 7,981.34 3,840.77 1,181.39 5,156.03 Start 1321.74 hold at 7981.34 MD 9,303.08 3668.97 50.96 5,840.39 Start DLS 2.50 TFO 44.24 9,371.33 3,869.70 -7.78 5,875.12 Start DLS 2.50 TFO 84.69 9,569.62 3,868.91 -183.57 5,966.75 Start 337.33 hold at 9569.62 MD 9,906.95 3,866.21 -489.12 6,109.65 Start DLS 2.50 TFO 88.01 10,509.79 3,858.70 -1,062.25 6,290.71 Start DLS 2.00 TFO 89.96 10,876.52 3,852.56 -1,426.45 6,331.13 Start 384.52 hold at 10876.52 MD 11,261.04 3,846.14 -1,810.50 6,348.99 Start DLS 2.00 TFO 97.77 11,361.45 3,844.70 -1,910.85 6,351.91 Start 5103.85 hold at 11361.45 MD 16,465.30 3,783.70 -7,013.99 6,411.98 TD at 16465.30 Checked By: Approved By: Date: Page 14 COMPASS 5000.1 Build 61 • • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-146 Plan: 1D-146 1 D-146wp04 Clearance Summary ' pti-Cull, Anticollision Report • TCR re red 30 September,2014 -- Tray Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan.1D-146-Plan:113-146-1D-146wp04 Well Coordinates: 5,959,107.65 N,1,700,704.57 E(70°17'57.22"N,149°30'42.22"W) Datum Height. Plan:(70.70+28)@98.7 t 98.70usft(Doyon 141) Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius is 2,383.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build. 61 Scan Type: Scan Type: 25.00 MMM • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 10-146 -1 D-146wp04 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-146-Plan:10-146-1D-146wp04 Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 1C Pad 1C-135-1C-135-1C-135 5,471.27 394.50 5,471.27 281.83 9,375.00 3.501 Clearance Factor Pass-Major Risk 1C-135-10.135-1C-135 5,466.56 394.17 5,466.56 283.18 9,400.00 3.551 Centre Distance Pass-Major Risk 1C-135-1C-135PB1-1C-135PB1 5,467.12 391.05 5,467.12 277.23 9,375.00 3.436 Clearance Factor Pass-Major Risk 1C-135-1C-135PB1-1C-135PB1 5,462.49 390.82 5,462.49 278.61 9,400.00 3.483 Centre Distance Pass-Major Risk 1C-184-1C-184-1C-184 7,307.94 131.23 7,307.94 125.91 11,890.00 24.647 Clearance Factor Pass-Minor 1/50 1C-190-1C-190-1C-190 6,319.91 52.03 6,319.91 51.43 10,400.00 86.724 Clearance Factor Pass-Minor 1/50 Kuparuk 1D Pad 1D-05-10-05-1D-05 366.95 193.78 366.95 185.69 375.00 23.975 Centre Distance Pass-Major Risk 10-05-1D-05-1D-05 2,211.07 195.59 2,211.07 144.19 2,400.00 3.805 Clearance Factor Pass-Major Risk 1D-06-1D-06-1D-06 98.70 189.65 98.70 187.80 105.00 102.274 Centre Distance Pass-Major Risk 1D-06-1D-06-1D-06 464.36 191.84 464.36 181.47 475.00 18.492 Clearance Factor Pass-Major Risk 1D-07-1D-07-1D-07 98.70 250.99 98.70 249.13 101.00 135.347 Centre Distance Pass-Major Risk 1D-07-1 D-07-1D-07 420.48 251.61 420.48 244.81 425.00 36.987 Clearance Factor Pass-Major Risk 1D-09-1D-09-1D-09 98.70 251.04 98.70 249.18 111.60 135.374 Centre Distance Pass-Major Risk 1D-09-1D-09-1D-09 384.23 253.16 384.23 246.69 400.00 39.107 Clearance Factor Pass-Major Risk 10-10-10.10-10-10 993.37 294.43 993.37 274.72 1,025.00 14.938 Centre Distance Pass-Major Risk 10-10-10-10-10-10 1,041.78 295.33 1,041.78 274.12 1,075.00 13.925 Clearance Factor Pass-Major Risk 1D-11-1D-11-10.11 416.74 329.80 416.74 322.93 425.00 48.015 Centre Distance Pass-Major Risk 10-11-10-11-10.11 515.26 330.34 515.26 321.96 525.00 39.442 Clearance Factor Pass-Major Risk 10-11-1D-11L1-10-11L1 416.74 329.80 416.74 322.93 425.00 48.015 Centre Distance Pass-Major Risk 1D-11-1D-11L1-1D-11L1 515.26 330.34 515.26 321.96 525.00 39.442 Clearance Factor Pass-Major Risk 10.11-1D-11L2-1D-11 L2 416.74 329.80 416.74 322.97 425.00 48.345 Centre Distance Pass-Major Risk 10.11-113-11L2-1D-11L2 515.26 330.34 515.26 322.01 525.00 39.664 Clearance Factor Pass-Major Risk 10.11-1D-11L2PB1-10.11 L2PB1 416.74 329.80 416.74 322.93 425.00 48.015 Centre Distance Pass-Major Risk 10.11-10.11 L2PB1-10.11 L2PB1 515.26 330.34 515.26 321.96 525.00 39.442 Clearance Factor Pass-Major Risk 10.117-10-117-10.117 312.23 283.13 312.23 277.46 325.00 49.931 Centre Distance Pass-Major Risk 1D-117-10-117-10.117 407.97 283.88 407.97 276.64 425.00 39220 Clearance Factor Pass-Major Risk 30 September,2014-15:55 Page 2 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-146-1 D-146wpO4 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 1D Pad-Plan:1D-146-Plan:1D-146-1D-146wp04 Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius Is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 10-119-1D-119-10-119 336.47 239.48 336.47 233.65 350.00 41.065 Centre Distance Pass-Major Risk 1D-119-1D-119-1D-119 432.37 240.16 432.37 232.80 450.00 32.603 Clearance Factor Pass-Major Risk 10.12-10-12-10.12 3,037.25 246.10 3,037.25 176.89 3,050.00 3.556 Clearance Factor Pass-Major Risk 10.12-10-12-10.12 3,077.39 244.58 3,077.39 178.93 3,100.00 3.725 Centre Distance Pass-Major Risk 1D-12-1D-12L1-1D-12L1 3,037.25 246.10 3,037.25 176.59 3,050.00 3.541 Clearance Factor Pass-Major Risk 10.12-1D-12L1-1D-12L1 3,077.39 244.58 3,077.39 178.70 3,100.00 3.712 Centre Distance Pass-Major Risk 1D-12-1 D-12L1PB1-1D-12L1 PB1 3,037.25 246.10 3,037.25 176.60 3,050.00 3.541 Clearance Factor Pass-Major Risk 1D-12-10-12L1PB1-1D-12L1PB1 3,077.39 244.58 3,077.39 178.70 3,100.00 3.713 Centre Distance Pass-Major Risk 10-12-1D-12L2-1D-12L2 3,037.25 246.10 3,037.25 176.60 3,050.00 3.541 Clearance Factor Pass-Major Risk 1D-12-1D-12L2-1D-12L2 3,077.39 244.58 3,077.39 178.70 3,100.00 3.713 Centre Distance Pass-Major Risk 10.120-1D-120-1D-120 98.70 231.27 98.70 229.42 111.60 124.715 Centre Distance Pass-Major Risk I 10.120-10-120-10-120 360.39 232.58 360.39 226.45 375.00 37.903 Clearance Factor Pass-Major Risk 1D-121-1D-121-10.121 98.70 222.33 98.70 220.47 112.00 119.893 Centre Distance Pass-Major Risk 10-121-1D-121-1D-121 360.05 223.21 360.05 217.07 375.00 36.340 Clearance Factor Pass-Major Risk 1D-122-1D-122-1D-122 61.60 214.09 61.60 212.61 75.00 144.981 Centre Distance Pass-Major Risk 1D-122-1D-122-1D-122 311.59 215.54 311.59 209.87 325.00 38.011 Clearance Factor Pass-Major Risk 10-123-10.123-10-123 236.59 205.47 236.59 201.37 250.00 50.031 Centre Distance Pass-Major Risk 10.123-1D-123-1D-123 286.58 205.88 286.58 200.95 300.00 41.703 Clearance Factor Pass-Major Risk 10.124-10-124-10-124 336.79 184.96 336.79 179.19 350.00 32.056 Centre Distance Pass-Major Risk 1D-124-1D-124-1D-124 409.22 185.52 409.22 178.63 425.00 26.904 Clearance Factor Pass-Major Risk 1D-125-1D-125-10.125 86.90 183.51 86.90 181.49 100.00 91.066 Centre Distance Pass-Major Risk 10-125-1D-125-10.125 384.64 184.62 384.64 177.83 400.00 27.187 Clearance Factor Pass-Major Risk 1D-125-1D-125A-1D-125A 98.45 183.51 98.45 181.56 100.00 93.977 Centre Distance Pass-Major Risk 10-125-1D-125A-1D-125A 395.80 184.79 395.80 178.04 400.00 27.402 Clearance Factor Pass-Major Risk 10-126-10.126-10-126 98.70 182.11 98.70 180.04 111.30 87.843 Centre Distance Pass-Major Risk 1D-126-1D-126-1D-126 237.39 182.73 237.39 178.73 250.00 45.596 Clearance Factor Pass-Major Risk 10.126-Plan:1D-126A-1D-126A(wp02) 98.70 182.11 98.70 180.04 111.30 87.843 Centre Distance Pass-Major Risk 10.126-Plan:1D-126A-1D-126A(wp02) 237.39 182.73 237.39 178.59 250.00 44.161 Clearance Factor Pass-Major Risk 1D-127-10-127-10-127 86.90 182.10 86.90 180.08 100.00 90.366 Centre Distance Pass-Major Risk 1D-127-1D-127-1D-127 161.90 182.47 161.90 179.62 175.00 63.889 Clearance Factor Pass-Major Risk 30 September,2014- 15:55 Page 3 of 10 COMPASS 111) • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-146-1 D-146wpO4 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-146-Plan:1D-146-1 D-146wp04 Scan Range:28.00 to 16,465.30 ustt.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1 D-128-1D-128-1 D-128 98.70 183.37 98.70 181.52 111.80 98.885 Centre Distance Pass-Major Risk 10-128-1D-128-10-128 360.61 184.42 360.61 178.29 375.00 30.100 Clearance Factor Pass-Major Risk 10-129-1D-129-1D-129 212.20 199.13 212.20 195.42 225.00 53.593 Centre Distance Pass-Major Risk 110.129-1D-129-10-129 262.19 199.66 262.19 195.13 275.00 43.997 Clearance Factor Pass-Major Risk 1D-130-1D-130-1D-130 361.11 205.57 361.11 199.44 375.00 33.498 Centre Distance Pass-Major Risk 1D-130-10-130-110.130 458.50 206.26 458.50 198.65 475.00 27.104 Clearance Factor Pass-Major Risk 1D-131-1D-131-1D-131 98.70 213.66 98.70 211.81 112.00 115.219 Centre Distance Pass-Major Risk 1D-131-1D-131-1D-131 186.70 214.30 186.70 211.00 200.00 65.011 Clearance Factor Pass-Major Risk 1D-132-1D-132-1D-132 98.70 221.88 98.70 220.02 111.90 119.651 Centre Distance Pass-Major Risk 1D-132-1D-132-1D-132 161.80 222.23 161.80 219.35 175.00 77.203 Clearance Factor Pass-Major Risk 1D-133-1D-133-1D-133 212.18 230.81 212.18 227.09 225.00 62.053 Centre Distance Pass-Major Risk 110.133-10.133-10-133 385.55 231.88 385.55 225.39 400.00 35.713 Clearance Factor Pass-Major Risk 1D-133-1D-133PB1-1D-133PB1 212.18 230.81 212.18 227.09 225.00 62.053 Centre Distance Pass-Major Risk 1 D-133-1 D-133PB1-1 D-133PB1 385.55 231.88 385.55 225.39 400.00 35.713 Clearance Factor Pass-Major Risk 1D-135-1D-135-1D-135 1,378.00 281.15 1,378.00 255.89 1,450.00 11.134 Centre Distance Pass-Major Risk 1D-135-1D-135-1D-135 1,558.15 283.73 1,558.15 253.00 1,650.00 9.234 Clearance Factor Pass-Major Risk 1D-141-1D-141-1D-141 1,961.72 109.94 1,961.72 59.46 2,050.00 2.178 Clearance Factor Pass-Major Risk 1D-141-1D-141-10.141 1,984.59 109.24 1,984.59 61.03 2,075.00 2.266 Centre Distance Pass-Major Risk 1D-141-1D-141A-1D-141A 1,952.09 110.73 1,952.09 59.22 2,050.00 2.150 Clearance Factor Pass-Major Risk 1D-141-1D-141A-1D-141A 1,975.06 109.32 1,975.06 59.88 2,075.00 2.211 Centre Distance Pass-Major Risk 1D-141-1D-141APB1-1D-141APB1 1,952.09 110.73 1,952.09 59.35 2,050.00 2.155 Clearance Factor Pass-Major Risk 1 D-141-1 D-141APB1-1 D-141APB1 1,975.06 109.32 1,975.06 60.01 2,075.00 2.217 Centre Distance Pass-Major Risk 1D-141-1 D-141APB2-1 D-141APB2 1,952.09 110.73 1,952.09 59.35 2,050.00 2.155 Clearance Factor Pass-Major Risk 1D-141-1 D-141APB2-10-141APB2 1,975.06 109.32 1,975.06 60.01 2,075.00 2.217 Centre Distance Pass-Major Risk 1D-141-1 D-141APB3-1 D-141APB3 1,952.09 110.73 1,952.09 59.35 2,050.00 2.155 Clearance Factor Pass-Major Risk 1D-141-1D-141APB3-1D-141APB3 1,975.06 109,32 1,975.06 60.01 2,075.00 2.217 Centre Distance Pass-Major Risk 1 D-141-1D-141L1-1D-141L1 1,961.72 109.94 1,961.72 59.46 2,050.00 2.178 Clearance Factor Pass-Major Risk 1D-141-1D-141L1-1D-141L1 1,984.59 109.24 1,984.59 61.03 2,075.00 2.266 Centre Distance Pass-Major Risk 1D-141-1D-141L1PB1-1D-141L1PB1 1,961.72 109.94 1,961.72 59.46 2,050.00 2.178 Clearance Factor Pass-Major Risk 10-141-1D-141L1PB1-1D-141L1PB1 1,984.59 109.24 1,984.59 61.03 2,075.00 2.266 Centre Distance Pass-Major Risk 30 September,2014- 15:55 Page 4 of 10 COMPASS I III • ConocoPhillips(Alaska)Inc.-Kupi Kuparuk River Unit Anticollision Report for Plan: 1D-146-1 D-146wp04 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:ID-146-Plan:10-146-1D-146wp04 Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius is 2,383.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) lush) usft 1D-141-1D-141L1PB2-1D-141L1PB2 1,961.72 109.94 1,961.72 59.46 2,050.00 2.178 Clearance Factor Pass-Major Risk 1D-141-1D-141 L1 PB2-1D-141 L1 PB2 1,984.59 109.24 1,984.59 61.03 2,075.00 2.266 Centre Distance Pass-Major Risk 10.141-1D-141PB1-1 D-141PB1 1,961.72 109.94 1,961.72 59.33 2,050.00 2.173 Clearance Factor Pass-Major Risk 1D-141-1D-141PB1-1 D-141PB1 1,984.59 109.24 1,984.59 60.90 2,075.00 2.260 Centre Distance Pass-Major Risk 10-28-1D-28-1D-28 568.36 38.94 568.36 29.53 575.00 4.141 Centre Distance Pass-Major Risk 10-28-1D-28-1D-28 3,685.52 120.21 3,685.52 24.29 3,450.00 1.253 Clearance Factor Pass-Major Risk 1D-28-1D-2811-10-2811 568.36 38.94 568.36 29.53 575.00 4.141 Centre Distance Pass-Major Risk 1D-28-10-2811-10-28L1 3,685.52 120.21 3,685.52 24.29 3,450.00 1.253 Clearance Factor Pass-Major Risk 1D-30.1D-30-10-30 1,298.10 44.02 1,298.10 22.06 1,300.00 2.004 Centre Distance Pass-Major Risk 1D-30-1D-30-1D-30 1,322.94 44.21 1,322.94 21.87 1,325.00 1.979 Clearance Factor Pass-Major Risk 1D-30-1D-3011-1D-30L1 1,298.10 44.02 1,298.10 22.04 1,300.00 2.003 Centre Distance Pass-Major Risk 1D30-1D-3011-1D-30L1 1,322.94 44.21 1,322.94 21.86 1,325.00 1.978 Clearance Factor Pass-Major Risk 1D-32-10-32.1D-32 823.61 100.85 823.61 87.04 825.00 7.304 Centre Distance Pass-Major Risk 1D-32-10-32-1D-32 925.68 101.87 925.68 86.21 925.00 6.504 Clearance Factor Pass-Major Risk 1D-32-1D-32L1-1D-32L1 823.61 100.85 823.61 87.16 825.00 7.368 Centre Distance Pass-Major Risk 10.32-1D-3211-1D-3211 925.68 101.87 925.68 86.32 925.00 6.552 Clearance Factor Pass-Major Risk 10.32-1D-3211 PB1-1D-3211 PB1 823.61 100.85 823.61 87.03 825.00 7.299 Centre Distance Pass-Major Risk 1D-32-1D-3211 PB1-1D-3211 PB1 925.68 101.87 925.68 86.20 925.00 6.499 Clearance Factor Pass-Major Risk 1D-34-10.34-1D-34 545.51 134.77 545.51 125.71 550.00 14.869 Centre Distance Pass-Major Risk 1D-34-1D-34-1D-34 645.97 135.94 645.97 125.21 650.00 12.664 Clearance Factor Pass-Major Risk 1D-34-1D-3411-1D-34L1 544.50 134.77 544.50 125.61 550.00 14.716 Centre Distance Pass-Major Risk 1D34-1D-34L1-1D-34L1 644.97 135.92 644.97 125.09 650.00 12.551 Clearance Factor Pass-Major Risk 1D-34-10-3411 PB1-1 D-34L1 P91 544.50 134.77 544.50 125.72 550.00 14.894 Centre Distance Pass-Major Risk 1D-34-1D-34L1PB1-1D-34L1 PB1 644.97 135.92 644.97 125.20 650.00 12.679 Clearance Factor Pass-Major Risk 1D-36-1D-36-1D-36WP4(Baker) 671.43 164.92 671.43 153.73 675.00 14.748 Centre Distance Pass-Major Risk 10.36-1D-36-1 D-36WP4(Baker) 823.94 166.23 823.94 152.22 825.00 11.869 Clearance Factor Pass-Major Risk 10-36-10-36-1D-36 570.81 166.88 570.81 157.52 575.00 17.841 Centre Distance Pass-Major Risk 1D-36-10-36-1D-36 824.31 168.88 824.31 155.00 825.00 12.165 Clearance Factor Pass-Major Risk 1D-36-1D-36L1-1 0-36L1 570.11 166.88 570.11 157.53 575.00 17.860 Centre Distance Pass-Major Risk 1D-36-1D-3611-10-36L1 823.60 168.86 823.60 154.98 825.00 12.166 Clearance Factor Pass-Major Risk 30 September,2014- 15:55 Page 5 of 10 COMPASS 110 • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-146-1 D-146wpO4 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:ID-146-Plan:ID-146-1D-146wp04 Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-36-1D-36L2-1D-36L2 570.11 166.88 570.11 157.53 575.00 17.860 Centre Distance Pass-Major Risk 10-36-1D-36L2-1D-36L2 823.60 168.86 823.60 154.98 825.00 12.166 Clearance Factor Pass-Major Risk 1D-37-10.37-1D-37 794.52 173.03 794.52 160.22 800.00 13.504 Centre Distance Pass-Major Risk 1D-37-10.37-1D-37 843.12 173.37 843.12 159.75 850.00 12.729 Clearance Factor Pass-Major Risk 10.37-1D-37L1-1D-37L1 793.44 173.03 793.44 160.24 800.00 13.523 Centre Distance Pass-Major Risk 1 D-37-1D-37L1-1D-37L1 842.06 173.35 842.06 159.75 850.00 12.744 Clearance Factor Pass-Major Risk 1D-37-1D-37L2-1D-37L2 793.44 173.03 793.44 160.24 800.00 13.523 Centre Distance Pass-Major Risk 1D-37-1D-37L2-1D-37L2 842.06 173.35 842.06 159.75 850.00 12.744 Clearance Factor Pass-Major Risk 1D-37-10-37L2P61-10-37L2PB1 793.44 173.03 793.44 160.24' 800.00 13.523 Centre Distance Pass-Major Risk 10.37-1D-37L2PB1-1 D-37L2PB1 842.06 173.35 842.06 159.75 850.00 12.744 Clearance Factor Pass-Major Risk 1D-38-10.38-1D-38 1,045.96 182.10 1,045.96 164.96 1,050.00 10.625 Centre Distance Pass-Major Risk 10.38-1D-38-1D-38 1,118.72 182.71 1,118.72 164.31 1,125.00 9.929 Clearance Factor Pass-Major Risk 10.39-1D-39-10.39 939.33 205.07 939.33 189.67 1,050.00 13.317 Centre Distance Pass-Major Risk 10-39-1D-39-10.39 1,012.42 205.77 1,012.42 189.19 1,125.00 12.410 Clearance Factor Pass-Major Risk 1D-40-1D-40-1D-40 874.80 217.82 874.80 203.61 875.00 15.327 Centre Distance Pass-Major Risk 1D-40-10-40-1D-40 924.85 218.24 924.85 203.20 925.00 14.508 Clearance Factor Pass-Major Risk 1D-40-1 D-40A-1D-40A 875.65 217.82 875.65 203.59 875.00 15.312 Centre Distance Pass-Major Risk 1D-40-1D-40A-1D-40A 925.70 218.26 925.70 203.20 925.00 14.495 Clearance Factor Pass-Major Risk 1D-41-1D-41-10-41 10,990.44 90.53 10,990.44 72.16 8,125.00 4.927 Clearance Factor Pass-Minor 1/50 1D-41-1D-41PB1-1D41PB1 10,990.44 90.53 10,990.44 84.01 8,125.00 13.873 Centre Distance Pass-Minor 1/50 1D41-1D41PB1-1D41 PB1 10,996.42 91.28 10,996.42 81.78 8,150.00 9.612 Clearance Factor Pass-Minor 1/50 1D-41-1041 PB2-1 D41 PB2 10,990.44 90.53 10,990.44 84.01 8,125.00 13.873 Centre Distance Pass-Minor 1/50 1D-41-10.41PB2-1041 PB2 10,996.42 91.28 10,996.42 81.78 8,150.00 9.612 Clearance Factor Pass-Minor 1/50 1D-42-10.42-10-42 975.06 252.15 975.06 236.22 975.00 15.831 Centre Distance Pass-Major Risk 1D-42-1D-42-10-42 999.55 252.48 999.55 236.13 1,000.00 15.448 Clearance Factor Pass-Major Risk 1D42-1D42-1D-42(Baker) 1,049.54 245.69 1,049.54 228.36 1,050.00 14.174 Centre Distance Pass-Major Risk 1D-42-1D-42-10.42(Baker) 1,097.63 246.23 1,097.63 228.07 1,100.00 13.556 Clearance Factor Pass-Major Risk 10-42-10-42L1-1D-42L1 974.08 252.15 974.08 236.45 975.00 16.068 Centre Distance Pass-Major Risk 1D-42-1D-42L1-1D-42L1 998.58 252.46 998.58 236.35 1,000.00 15.673 Clearance Factor Pass-Major Risk 1D-42-1D-42L1PB1-1 D-42L1PB1 974.08 252.15 974.08 236.23 975.00 15.847 Centre Distance Pass-Major Risk 30 September,2014- 15:55 Page 6 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-146 -1 D-146wpO4 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-146-Plan:1D-146-1D-146wp04 Scan Range: 28.00 to 16,465.30 usft.Measured Depth. Scan Radius is 2,383.08 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 1D-42-1D-42L1PB1-1D-42L1PB1 998.58 252.46 998.58 236.13 1,000.00 15.463 Clearance Factor Pass-Major Risk Plan:1 D-142-Plan 1D-142-1D-142wp06 300.00 60.01 300.00 54.51 300.00 10.923 Centre Distance Pass-Major Risk Plan:1 D-142-Plan 1 D-142-1 D-142wp06 524.11 61.47 524.11 52.32 525.00 6.722 Clearance Factor Pass-Major Risk Plan:1D-143-Plan:ID-143-1D-143wp12.1 1,121.86 25.38 1,121.86 6.76 1,125.00 1.363 Centre Distance Pass-Major Risk Plan:1D-143-Plan:ID-143-1D-143wp12.1 1,146.62 25.60 1,146.62 6.64 1,150.00 1.350 Clearance Factor Pass-Major Risk Plan:ID-143-Plan:ID-143-1D-143wp13 Plan: 1,121.86 25.38 1,121.86 6.76 1,125.00 1.363 Centre Distance Pass-Major Risk 1D-143-Plan:1D-143-1D-143wp13 Plan:1D-143- 1,146.62 25.60 1,146.62 6.64 1,150.00 1.350 Clearance Factor Pass-Major Risk Plan:1D-143L1-1D-143L1wp12.1 Plan:1D-143- 1,121.86 25.38 1,121.86 6.76 1,125.00 1.363 Centre Distance Pass-Major Risk Plan:ID-143-Plan:1D-143L2-1D-143L2wp12.1 28.00 30.00 28.00 28.99 28.00 29.686 Clearance Factor Pass-Major Risk Plan:1 D-143-Plan:1D-143L3-1 D-143L3wp12.1 1,121.86 25.38 1,121.86 6.76 1,125.00 1.363 Centre Distance Pass-Major Risk Plan:1D-145-Plan:ID-145-1D-145wp06 1,633.26 52.78 1,633.26 26.91 1,650.00 2.040 Clearance Factor Pass-Major Risk Kuparuk 1J Pad 1J-122-1J-122L2-1J-122L2 15,490.23 1,095.20 15,490.23 868.07 16,675.00 4.822 Clearance Factor Pass-Major Risk 1J-122-1J-122L2-1J-122L2 15,415.23 1,095.01 15,415.23 868.28 16,750.00 4.830 Centre Distance Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 1,200.00 1D-146wp04 GYD-GC-SS 1,200.00 2,710.00 1D-146wp04 MWD 1,200.00 2,710.00 1D-146wp04 MWD+IFR-AK-CAZSC 2,710.00 3,700.00 1D-146wp04 MWD 2,710.00 7,805.87 1D-146wp04 MWD+IFR-AK-CAZSC 7,805.87 8,805.00 1D-146wp04 MWD 7,805.87 16,465.30 1 D-146wp04 MWD+IFR-AK-CAZ-SC 30 September,2014- 15:55 Page 7 of 10 COMPASS • 0 ConocoPhilhps 1 D-146wp04 Schlumberger Alaska c a n ., e M 0• d a C \ ; ,,..h. , . ..■.nllliiii11liI1 0"0 I / ,o asQ 060 1111IIII1p III . I� co -..■■ '1 1 J I � I � ildf o Ise ii�l� i liA. V IIUhIIIIjiIIhhhuh1JJJiJJ!! �� — Equivelant Magnetic Distance 0 I I i I I I I I 1 1 I I I I 1 I I I I t I r I I j I I I 1 t I 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire rairbinttured Depth 28.00 To 16485.50 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 16465.30 Results Limited By: Centre Distance:2383.08 NO GLOBAL FILTER:Using user defined selection&filtering criteria SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1200.00 1D-146wp04(Plan: 1D-146) GYD-GC-SS 1200.00 2710.00 1D-146wp04(Plan: 1D-146) M W D 1200.00 2710.00 1D-146wp04(Plan: 1D-146) MWD+IFR-AK-CAZ-SC 2710.00 3700.00 1D-146wp04 (Plan: 1D-146) MWD 2710.00 7805.87 1D-146wp04 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC 7805.87 8805.00 1D-146wp04 (Plan: 1D-146) MWD 7805.87 16465.30 1D-146wp04 (Plan: 1D-146) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2355.70 2707.53 13-3/8"x16" 10-3/4 3835.70 7805.87 9-5/8"x12-1/4" 7-5/8 3783.70 16465.30 4-1/2"x6-3/4" 4-1/2 MD Inc Az: TVD -,W-S +E/-W DLeg TFace VMI.rget 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 1 D-1 46wp04320.00 0.00 0.00 320.00 0.00 0.00 0.00 0.00 3 700.00 4.18 110.00 699.66 -4.74 13.02 1.10 110.00 13.64 28 500 41200.00 16.67 106.98 1190.44 -32.03 99.08 2.50 -4.00 103.14 28.00 To 16465.30 51700.00 25.05 84.30 1657.98 -42.50 273.60 2.30 -55.00 276.82 500 - 800 6 2750.00 68.00 52.00 2372.24 299.37 916.16 4.56 -41.94 850.25 7 4500.00 68.00 52.00 3027.80 1298.33 2194.76 0.00 0.00 1935.97 800 1 100 8 6205.00 68.00 87.00 3684.06 1840.84 3645.79 1.90 96.74 3270.74 YG.Cd,�a..�...:.a:.9A:- Kh.: 96604.63 86.42 89.38 3772.15 1852.80 4033.61 4.65 7.48 3650.60 1100 - 1400 10 6609.82 86.42 89.38 3772.48 1852.86 4038.79 0.00 0.00 3655.69 11 7805.87 88.00 145.00 3835.70 1327.93 5059.73 4.65 89.97 4752.27 1D-146 15May14 T1 MW 1400 1700 12 7825.87 88.00 145.00 3836.40 1311.56 5071.20 0.00 0.00 4766.40 GLOBAL FILTER APLLIE 13 7981.34 149303.08 88.78 148.81 3868.148.81 97 1181.39 5156.03. 00000 78.52 487256. 1700 - 2000 15 9371.33 90.00 150.00 3869.70 -7.78 5875.12 2.50 44.24 5787.22 1D-146 15May14 T2 MW 169569.62 90.46 154.94 3868.91 -183.57 5966.75 2.50 84.69 5907.98 2000 2300 17 9906.95 90.46 154.94 3866.21 -489.12 6109.65 0.00 0.00 6101.76 ,t11 From Deem 7o splvP7,P.n ,Oa 180509.79 90.96 170.00 3858.70 -1062.25 6290.71 2.50 88.01 6379.60 1D-146 15May14 T3 MW 2300 2600 28.00 1200.00 10.146wp04(P61n:10.106) GoD-GC-es 190876.52 90.96 177.34 3852.56 -1426.45 6331.13 2.00 89.96 6482.64 1200.00 2710.00 10-106wr04Mk.10-106) MWD 201261.04 90.96 177.34 3646.14 -1810.50 6348.99 0.00 0.00 6566.92 2600 3000 1200.00 2710.00 10.106wp04(Rem 10-1.16) MwD.irA.ixcazsc 2111361.45 90.68 179.33 3844.70 -1910.85 6351.91 2.00 97.77 658723 1D-14615Ma 14 T4 MW 2710.00 3700.00 D-106wp04(Pbn:1D-106) MWD y 2710.00 7605.87 10-146,04(Mem 113-106) 4WD.I...-C2.SC 226465.30 90.68 179.33 3783.70 -7013.99 6411.98 0.00 0.00 7532.54 1D-146 15May14 T5 MW 3000 3400 7805.87 6805.00 10.146wp00 Mt.. 10.1461 MWD (P 7605.87 16085.30 10-1.1.P. ..10.1061 MWD.16a-A.CAZ-SC 3400 3800 CASING DETAILS 3800 4200 ND MD Name Size 2355.70 2707.53 13-3/8"x16" 10-3/4 4200 4600 3835.70 7805.87 9-5/6'312-1/4" 7-5/8 3783.70 16465.30 4-1/2"x6-3/4" 4-1/2 4600 5000 5000 - 5400 0/360 D-411 1 ho- 41PB1 5400 5800 \'.mirLa�i s,4p1-!.�giII.-SOP►ii 5800 7200 -30/330 I44F-14'•4' 1 11IN,air����p�y�v' 7200 30, 7200 8500 144....4,11002--414/041111111111111i01//119,•-p4plje meq i "' E _ -___ D-41P8 , 1 �,.,/pl64Al.af1 i+ 4 8500 9900 lzlea``:` ���r,�i4iiii WierfriiNfet/ri / ►4' , �., 9900 11200 y f.r/It is W l#j�7IG► kiQhr, r r 4 1 � t f \, `y►s•sir 7' /mo ,4 tR� aOr�� � �ik 11200 12600 I�" Inl 11 ,` � � /'d/ ♦j�7,�' , a' �.. 9 U+0411 4y::�� -s wN ,<y��ralii' J a.,� /I++D+1115 `�'�o��' ���.��� 1 d� A� I4jQ 12600 13900 r fiNiats ®�� ,.:.,,,,too -4;11`,•Oai'.- o �AAtire, N .'10 `ati 13900 15300 �6'�► Com\ �i dip•, 4+ 02/11,,;•••=:;,;',;34.•;•.•TAI* lie 9►► �'4:'�' - 15300 16643 -60/300 `/ 1���2J 1.40i', .' > ,' 80 N1, l� �1 �ftd_, 60 // �440/011,10A-4a•� •n° r1// ,7 F. , i4V,� �, ii// ' 4i ,,44t � �j War of C Ail-..flplc:•At,,p.00,,,j, i 70 ------, tii.� ♦4�i ♦ r ,W4a+10,01 it o-1a3w1z. 4.4,104. �•i. 1 �y(,44('iiiQ�.•�p0 7 gal. 1096-,... h P 1 1,-,A. 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I -.1.IyiM�f' s, ���r®�, ► P �. � i,,, -�c..,,�<, kit, .►s 6, -120/240 q.A a �, i •� �� 21 ip►, r 1 6 D-32L1P6 H 1P� �'�� Irk�� � _ 1►�-,.";0.410000,0r,',... e 000��0,0A4@ I) ��� tt-ti, .�t�i hD-141 L1P -32L1 ho-la2wPo�"_ •_��� ��t`,,wh ,1 rii(f4t �Iv 4 VAile' - m►; sy•.:a halasw 150/2104 Pir f � ��(Ci'f lg gom G1 ` z---ho-34L>I _ fji:.e, �� i4.. .R:t.i..4� �k`- hD-34L,PBI 11c-190 -180/180 11D-3'1 D-30L11 miNok Ristai . . _._ ,....1‘,190,10190 22 -9- 13.125.,0,16632 + , + , + W o- -} + mA1 Pp Pp + ; -3- ; 342130vs W .e, 1.96,1636,1D. 44- Po $ 10 10 $ , i 136P6L231 17, -4 0,142M W .. , $ , �x1�6 $ 1 -•- Pa 4. 1.141.10 � 1� -0- 1 $ , 00;02'7'- 44- , .11.131 22 jE 10193,16139.1.139 32 + , -0- 1072. 04 � , 22 � 1 + 1 + ,a - ;06, ,W -8- 166 -x- 1042 �. 113 $ 1.97.13.97 1.37 34 + , -tr 042124021 $ , $ 1017.10,71.2.10-071.2 V5 $ , 34051'3-44201 a , + , a , $ 10; " . 1� 4. ,om -0- ,D M W + 1 + 10 13.31 317 .fr 1.128.1.128.1.129 W ,D --X- ,D.184,1C 184,1.18410 9 ,0 -l- 10, DA, 1 D-1 46wp03 7 . 156 Plan Sum ary SURVEY PROGRAM )ept I From Depth To Survey/Plan 28.00 1200.00 1D-146wp03 (Plan: 1D-146) GYD-GC ...._, Ili' .„,, 1 W0.00 2752.53 1 D-146wp03 (Plan: 1D-146) M .,� ,;/ \�. �, 1 W0.00 2752.53 1 D-146wp03 (Plan: 1D-146) :::: -AK AK CAZ- /011(11$10,11111117� . .; CASING DETAILS444411 °� �� ‘4,1:'''':::,"2:::'''' -1-1-2*::::I. ,,- TVD MD Name Size �� 2355.70 2752.53 13-3/8"x16" 10-3/4 itf:1-7� 3835.70 7780.30 9-5/8"x12-1/4" 7-5/8 3784.20 16397.98 4-1/2"x6-3/4" 4-1/2 ,"` t - t3 k15 13-3/8"x16" Top W Sak - o 0° �6_ '., ,' uga N 1 9-5/8"x12-1/4" -5 80 13-3/8" 16" ugb 1- 1=- 0 1®, `m . r-'r�ugc , '. 0 20 O �, 5I 1 - u, 4-1/2"x6-3/4" u) `. ‘ r 1 r o$0 . 9-5/8"x12-1/4" - ‘ t 1 4-1/2"x6-3/4"- . M s m •a a r , ✓T - , ,, L - o o r , 0 ' I` 1 o h Qmo a °a° \ - Base Permafrest i -1 c7 °pj 0 i I 1 I I I I I I I ` I I I I I I 0 I I I I I I 1 L r 8 CJ 14I d 10 p l 0 4000 8000 12000 160100 0 2000 4000 6000 300° 1200[' 12000' 181380 Measured Depth Horizontal Departure • I' \ 330 0 30 8 60 . \, Son •�`'4� e"...°:::::-0 � °*S4� .so „� - oro °41► 1 �a ,D 281_1 - 270 ' t 000 .s5 ¢A U 30 • AN c• -- ,, P(,t 90 - ' �� l Rw..eD tat PE 42. 4.0 - 92 !� sora - 5. 240 ,1,, P Y 120 WOO 6 � emo U• - I'. �.*l\ sero - MOO o 1 1 1 1 1 1 1 I I I I I I 1 I 1 'r J I I I 1 1 1 1 I • �� ''' 0 2000 4000 6000 8000 10000,. 12000 14000 16000 210 .30L}51 180 moo _ CSEIT-0 '.iETAILS 15300 - 15643 Sec MD Inc Azi TVD TVDSS +N/-S +E/- • Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -70.70 0.00 0.00 0.00 0.00 0.00 - 1654.7 2 380.00 0.00 0.00 380.00 281.30 0.00 0.00 0.00 0.00 0.00 3 700.00 4.80 99.00 699.63 600.93 -2.10 13.2 1.50 99.00 13.23 Base Permafrost 4 1200.00 17.29 95.36 1189.40 1090.70 -12.35 108. 2.50 -5.00 108.23 5 1700.00 28.00 78.12 1650.67 1551.97 4.94 29 .81 2.50 -40.00 297.81 1865.7 6 2785.00 68.00 52.00 2368.19 2269.49 385.77 • 6.85 4.04 -36.14 976.85 7 4500.00 68.00 52.00 3010.64 2911.94 1364.75 - 29.89 0.00 0.00 2229.89 t3 8 6205.00 68.00 87.00 3666.91 3568.21 1907.26 4680.91 1.90 96.74 3680.91 9 6682.48 86.06 99.89 3774.05 3675.35 1877.58 4142.26 4.60 36.51 4142.26 -2120.7 10 6800.17 86.06 99.89 3782.14 3683.44 1857.41 4257.93 0.00 0.00 4257.93 11 7780.30 88.00 145.00 3835.70 3737.00 1345. :. 5062.44 4.60 88.90 5062.44 1D-146 15May14 T1 MW 12 7800.30 88.00 145.00 3836.40 3737.70 132•:'9 5073.91 0.00 0.00 5073.91 13 7955.77 88.78 148.81 3840.77 3742.07 11••.02 5158.75 2.50 78.52 5158.75 14 9277.51 88.78 148.81 3868.97 3770.27 .;58.59 5843.10 0.00 0.00 5843.10 15 9345.76 90.00 150.00 3869.70 3771.00 9.85 5877.83 2.50 44.24 5877.83 10-146 15May14 T2 MW 16 9544.05 90.46 154.94 3868.91 3770.21 f'-165.93 5969.46 2.50 84.69 5969.46 17 9881.38 90.46 154.94 3866.21 3767.51 1 -471.48 6112.36 0.00 0.00 6112.36 k15 18 10484.22 90.96 170.00 3858.70 3760.0 -1044.62 6293.43 2.50 88.01 6293.43 10-146 15May14 T3 MW 19 10851.07 90.96 177.34 3852.56 3753 6 -1408.93 6333.84 2.00 89.96 6333.84 20 11235.83 90.96 177.34 3846.13 374 .43 -1793.22 6351.71 0.00 0.00 6351.71 21 11335.88 90.68 179.32 3844.70 37:6.00 -1893.22 6354.63 2.00 97.94 6354.63 1D-146 15May14 T4 MW 22 16439.74 90.69 179.33 3783.70 85.00 -6996.35 6414.70 0.00 49.34 6414.70 10-146 15May14 T5 MW / -3138.7 ugc -3345.7 ugb 34788..7 -3577 .7 N -37�.op W Sak Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 TM Depth Reference: Plan:(70.70+28)@98.7 @ 98.70ft(Doyon 141 Magnetic Model Date: 22-Jan-14 System(SS) Reference: Mean Sea Level MagneticnRecreation: a True �d North /Y: 5959090.00 around Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.62°East *Et East/X: 1700702.00 Rig: Doyon 141 NO GLOBAL FILTER:Using user defined selection&filtering criteria ORIGINAL • • ` i°.3f ,igeNritfi ,�:., , 5EKR S,, , gym„ t. t • "0 d p d OD c •- r -0 Od 't- 3_ L D cu V ca '' E " ~ � ....=some N▪ r O y = i •CA r a 04.' ▪ N ' v ami V I V Q N V 03 Co uDch •� 3 L U) CD LL (V Ele /N \V Q COa Lill • MINIM 015 s = M E aD "0 oCL E LL r r r r CO r 4 Y Y o 0 0 N = r r r O Q Q c C •• E V YYaa a 13- i, ORIGINAL 0 1/10 a) co a_ z o Z co N co , co co coO co Oo V V co O •Q V n 0 C C M O N b N 0 O O co (/) O O O 0) n Zr) Q 0 0 0 Q 0 0 Z N n 0 O co U ` o a Uw co @@N j U N U N N Z a j U O O U Y J a' 7 )p a1 N -00 .. �" O Q U) > O) y d d C C a) - rG C O) 01 CD J -, m ) ` C a 0 C c V a ,.0. C aa1- � W 2 > > c c 'o J -I 0 G) > ui7 O a w 0 Lo ii .c a C .a `° d L J J a .0 a) a/ 0) 0 g c cc E p a., (A 2_ asC d o a c0c = 0a C ai0 LL 4 i Nw A R0 O w mi a) 0 : a= V _ o 0 0 (� 0 .a, j 0 110 co O Q coO O r O O 0 T I I I 1 Q _ 43) 1 11 O ■ i LCA C o p O O O O O t�^fi o T N CO '1- Ln Co W T T T T T T-aT" 0as f -. O �0 O a0 •ct CO o� CO x I'- N - Q r O PZ 0 T —0 C N a--. x O O 0o Ln Ln .D0O CI) O '+ ,00 co in ISP O 4) X O Co O QQQ ^Ln - T Q` T M .00 0 0001. 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O o N Z -E,,,_ Q = ` 1 . _O � ' O N- = "009\. c) o CO O 0 `I O 0) O = 76 C 000 O 00 }, U co O C/) U 4) O O 0L CL EN O O ct co 00 099 7I a Q O o O Xo 06 i Co co o0 ° r- 0 0 o O O o 0 0 o O O O (u!/IT 00L) 1-11000 eapaA ana1N CO ORIGINAL 0 0 a) l ....„,......_ ._ k ® x I 0 cnM i i /i'.5 N (V X W M co \ , \ ",f, M O am \ \ , , CD dm \ ,,,1- a 1 0 T ORIGI \ AL 0 4110 Northing (3000 ft/in) _ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ( I I I I I I I I I I I I I I I I I I I I I I I I 1 1 I_ sr - o - N - CO - d CO _ ✓ d ` 0] (p d - Q T _ co N _ Q - ,- J.I. in J J mC,7 — J Q O co CN7 d ,- NN Q Q J T _ NT 13 Q — O iJ - - N 'N r N M ..„..........),J - U Q m r N n Q ili - — T 0-J_ M — O O) ` i JN a,. C w T I T w U G NQ M— , �\ rat �T (� M —O . - \ JO. __, . c.., i T a1 c _ I I� o-r '_ �d al - C_ RI - ' io P. ppm CO al W 1 _ o f- d W Q:: , . ,... •-•14rAIIMMI, M — . Q CZ 7/r'r--- 1 Oii. ., N `� 0- ,___ _ CO.. •../ \ P. (00191Pr e. 4±1 el,- O T ctia 3 Q 1�r c. 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N CO Ce) 3 d ddd d dddd d d d d d d d d d d CO d CO d66dd '- co O) O N M M r r r r r r r r r •- r r r r r N (N N CO co co co co co V V V '- V V V ' N N 2 OM M M 1),,i.., M a d d d d d d d d a a d d d d a a d d d a d d d d d d 0 - 0 N ',. .... ,..._ O py O l} 6..d •1 A 1 . _^__O • _ 0 --_ _ - —o • `_ '. - Q) —o O __ ; -- - _ O CL • ol +. - 0 y –0 CO o �y M p D �, Q. • .c CD as d' ar - o0 O E . c _r i' Q � . CO d co « —. N • ! i ,• , . Ala. Ca - r r �� 7., I o d -- a o �- _ __'4 .moo Lm i-�, _ 0 133 • :r' oN % d ! Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace Target 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 1 D-146wp03 0.00 0.00 0.00 380.00 0.00 0.00 0.00 0.00 28 500 3 00.00 4.80 99.00 699.63 -2.10 13.23 1.50 99.00 .3 4 1200.00 17.29 95.36 1189.40 -12.35 108.23 2.50 -5.00 108.23 28.00 To 16440.25 5 1700.00 28.00 78.12 6 6 2785.00 68.00 52.00 2368.19 385.77 97 0 7 500 800 6.85 4.04 -36.14 96.85 7 4500.00 68.00 52.00 3010.64 1364.75 2229.89 0.00 0.00 2229.89 800 1100 8 6205.00 68.00 87.00 3666.91 1907.26 3680.91 1.90 96.74 3680.91 13:47,Mav 21 20149 6682.48 86.06 99.89 3774.05 1877.58 4142.26 4.60 36.51 4142.26 1100 1400 10 6800.17 86.06 99.89 3782.14 1857.41 4257.93 0.00 0.00 4257.93 11 7780.30 88.00 145.00 3835.70 1345.56 5062.44 4.60 88.90 5062.44 1D-146 15May14 T1 MW 1400 1700 12 7800.30 88.00 145.00 3836.40 1329.19 5073.91 0.00 0.00 5073.91 GLOBAL FILTER APPLIED: 14 92»:51 8878 14841 386897 116859 5843.10 000 7000 5843.10 1700 2000 15 9345.76 90.00 150.00 3869.70 9.85 5877.83 2.50 44.24 5877.83 1D-146 15May14 T2 MW 16 9544.05 90.46 154.94 3868.91 -165.93 5969.46 2.50 84.69 5969.46 2000 --- 2300 17 9881.38 90.46 154,94 3866.21 -471.48 6112.36 0.00 0.00 6112.36 Moth From Deem To Survey/P.. ]ae, 18 10484.22 90.96 170.00 3858.70 -1044.62 6293.43 2.50 88.01 6293.43 1D-146 15May14 T3 MW 2300 2600 06.00 1200.00 113.14000040 000:10-146) DVD-CC-$S 19 10851.07 90.96 177.34 3852.56 -1408.93 6333.84 2.00 89.96 6333.84 1266.00 2]52.53 10-146wp00(0,0,:10-106) bFW0, 20 11235.83 90.96 177.34 3846.13 -1793.22 6351.71 0.00 0.00 6351.71 2600 3000 1200.00 2]52.63 10-146wp03(PIen:16146) ��IFRFN-C.I2SC 21 11335.88 90.68 17932 3844.70 -1893.22 6354.63 200 97.94 6354.63 10-146 15May14 T4 MW 2]52.53 425260 10.146wp03(Plan:10140) y 2752.33 ]]60.30 10-146001,03(P00:10-146M1fiVDaIFRAN-CAZ-SC 22 16439.74 90.69 179.33 3783.70 -6996.35 6414.70 0.00 49.34 6414.70 1D-146 15May14 T5 MW ]]80.30 6460.74 1D-146wp03(Plan:1D-146)) 3000 3400 ]]60.30 16439.4 10.146wp03(Plan:10--146) M1NJD.IFRAKCPZSC 3400 3800 CASING DETAILS 3800 4200 TVD MD Name Size 4200 4600 2355.70 2752.53 13-3/8'416" 10-3/4 3835.70 7780.30 9-5/8"x12-1/4" 7-5/8 4600 5000 3784.20 16397.98 4-1/2106-3/41 4-1/2 5000 5400 0/360 5400 5800 !ge.Sy4-filEitt. .0-XIPOPF1I� 5800 - `" 7200 �J4TPi;Sd,44. i1 1 1l .rif®C/e``a °Q�sdBb'fl��Irl✓"Fi{®@gs�l� 7200 8500 -30/330 i•m El•sa ea�a�s� Melia. 1/y.�seC1111 30 gy X00\q ,tr1i /• $ olid 11. t!lf,-.,e, ��y�� if ��l a 0-"-41 `L 8500 20 r t rr ® ®'r i a�4S, ! ' ��°1 l l ,,e I .. , 9900 - 11200 E¢0y 5 is .9/40lain ; ,* ®sfd/4,[Pr! 'g%`jr• �®'i�®/ i "i//'�1!,F.. 11200 12600 ®. ®%iS ,,�� tVp�•�l)�o \Veli gi,i: /gi%, oi. ,.7ildr 4-tv"gvp cert s i`k! ress .75, 12600 - 13900 or, 'i%✓`1 i�i�®a tli.0- tf" /' ,�I�e i®gl'&'i .,04,3®`\`d'4� 13900 15300 ���V V. ` %sd, F.- ini ate! v,-, �igii�1',A 4,p ifkf L\ 15300 16643 60/30 fll�'4, FF �; 4�� c •Tw1if�,�• �' j� s• ®7,11,,ANT' iii �X,960 pet i!r .•y'r rer�i " a�@IP9p� • r: >e wi►tr l' � • A ♦ fi�i 116\ ./ r ®milia ♦ 4j p� ,ti �a �r_`t�i'� 11.i� t. ,j. y ,i.� 4 9r®!<'.*s Q 4,ta,i4,;,,. c i ��. (•fir/ jW � / ry'1��Y *�. �.di�t4li/®.i ��, 1„ '"-selaar 4 t"a! y �.1" �► H//ll1 7®s. �/�117 r! 1�D . P V���i elip �i��i%I'��. ���1�71�/�,�.ls® i6r �,A�t�$d �q'+ ;�@y r�` ►j�N�l�Aa t+S{ li �. 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J'`,: Lan �+Al 1• .®7� /,q✓!+ . p;e d11 .{ A i �I16 77: 44i�g1;�'�j,sVt,t',4eAt Nr. iR`�� ,( 10- 4►a/r! `�l � "'N • !1 \,1 �is/te y, xis\®A �V�'S a`pfr^"' i v /�1 F lia*•;0 0V .#_ N'.: di iQi �diarAler. hitt:; ,. - tea --.,::k7;,-,...'•'$•:,i:'::;',b �6 21 ft )4 �'� A 43 ► w,q !\.s s a Alf!• SOY c l` v'� nR\\ 1 it 1 ' 6 9 r rAl pl/44 '.mg \, r aaa A\ t- ,u .`. 1,,... 11 r! 1� 4:11,® I� I Otiraae / A!iarar 1;11 t A� 44al ,!1 / m 4v d11 t„1• r l i1�+� e``�i,,' ��g iiia 1 dr. %4 p♦ r.n� i+IP�.( ei�� r1 1rr _,,,..6,,,���OiV1\��, ' 7 Fi` f s ! Dlr 7� °j�I}+i�I✓�#��.� ��' t s 4r .... s 'f.4'4,441;44if,*i`►i' h,��s- �t�� I Gil <�irFb ♦ II �'t. Yrwpiti!i+R1w`s\7*` ��'� �4,� 11 ( .� f i 13 ri?�`I , 'r, 'I l if i V �� t �4+ �� ,i/i;.-P.;-)-- o>y 1 ®a p slFirt/ �4 fj.. *...,-.0,01,,, A .> ,,fi�g • •41, ���1�ilijk1ll1� °7 ! / a�li -120/240 py �%AV '. ,e•;� ` ILti11 "'� w,ti8t,AA'.1 d 4i r ��� '1l 11\� \��s�` ly 'ri fl+ i! k'Ml�zi1 Pali tV r 111 ��a p o1G 120 :� � �!A5�'®�x '�� 11,1%. 6, ® • )♦p� 84o!?A�liriiiy 4i�,1,�„ �4..ti11::1 • ��►1� `\®o!®1>� ;1i3® :4� 0,,41 it te lA tf�i �maI F [�a$ 1 R-.� � Vn� °,V1111 � i � .. : \�it toN 14ams:sR4a1 .4.:tIt _ 150/210 , ljt�' ®, . _ 150 kil ; ?:.;+-'::•..";-''. _ 1b1,+ ' ®'«y, 111i✓ -180/180 ~ Ated TCR required 4041,1221.1.1141.1,1/122.14/122.6V0 i- ,124,,D124V.2 } , ,s,Fe2,10.141L1002V2 .111, ,630103010-3902 4 s .. 28606,;: 12:;J10002 16 .a D;26,;o;2,:;a00000 a 10;02 6 ;0-00-0 aa4, $ 10136,1,10I0i1502 43. D126,1,126.10.12602 $ ; $ , a $ Mare s , -e▪ 0,,40;0:40:;0,,40*0 $ (3-127,0-;0:;a;28*2 -x- ,6�:;�2,,03265 ,10-41.10.1111621,411:. 4€ Das.,00sys -- 012%10-125v2 .g. , ♦ 10-40.10-40.10-4218.0. -1c- 10441006,00609 + o 1,130,1,130 V2 -fr 1�,;�;Pel,0 106141 .fr. 16421042<,.,D420VI -d1• •fr 3311,1D,31,1D131 V2 -a- ,634.1034,1634 Ve -x- 7040,10.21.1P61.t0-2201P01 V, oto,.0':0000 -b- 0.122,1613216,0202 -,e- ,634,1D3.,.10340107 + 0-142,142.0640 -8- ,614,D14,D10V2 i- 16133.1,133 v2 $ , ,P6104 - P. ,143,6143,12 V0 '� ],,0.,17,,0.n]V2 $ 11133,16133PB1,3D,00P61 V2 $ 1,36.1.36.1036044 PYn 43L104312 v0 -e- , ,9 na10.n9V2 -N- 6135,166,36,6135 V2 'e. , W�;16rw1 V1 � Pan,10.143,P4n 10-14312.,0'14312.01200 -X- ,12,1001 11112,1131 -Z- 1 0.,11 V2414 6 2 l5eyya<<<i I $ P6016145,Nen.10145,1614500 0 V0 ▪ �o�m m'ao�o,'m va,Pfi,VO 0101,1 1.incea'io a 1 �1.; 'nz�ITTiv $ '101.00-COO 6,46.,6,+w®w Sec MD Inc Azi ND .1.1/-S -FET-W .Leg TFace Target 1 8.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 1 D-146wp03 30.0.00 4.80 99.00 699.63 2.110 13.23 1.50 99.00 .3 28 500 4 1200.00 17.29 95.36 1189.40 -12.35 108.23 2.50 -5.00 108.23 28.00 To 16440.25 5 1700.00 28.00 78.12 0 297.81 6 2785.00 68.00 5200 2368.619 385.77 976 .85 4.04 -36.297.81 2.50 14 976.85 500 800 7 4500.00 68.00 52.00 3010.64 1364.75 2229.89 0.00 0.00 2229.89 800 1100 8 6205.00 68.00 87.00 3666.91 1907.26 3680.91 1.90 96.74 3680.91 13:49,May 21 2014 J9 6682.48 86.06 99.89 3774.05 1877.58 4142.26 4.60 36.51 4142.26 1100 1400 10 6800.17 86.06 99.89 3782.14 1857.41 4257.93 0.00 0.00 4257.93 11 7780.30 88.00 145.00 3835.70 1345.56 5062.44 4.60 88.90 5062.44 1D-146 15May14 T1 MW 1400 1700 12 7800.30 88.00 145.00 3836.40 1329.19 5073.91 0.00 0.00 5073.91 13795577 88.78 148.81 3840.77 1199.02 5158.75 2.50 78.52 5158.75 1700 _._ 2000 LOBAL FILTER APPLIED 14 9277.51 88.78 148.81 3868.97 68.59 5843.10 0.00 0.00 5843.10 15 9345.76 90.00 150.00 3869.70 9.85 5877.83 2.50 44.24 5877.83 1D-146 15May14 T2 MW 16 9544.05 90.46 154.94 3868.91 -165.93 5969.46 2.50 84.69 5969.46 2000 2300 17 9881.38 90.46 154.94 3866.21 -471.48 6112.36 0.00 0.00 6112.36 fpm Prom Dram a Survey/Plan 7a9i 18 10484.22 90.96 170.00 3858.70 -1044.62 6293.43 2.50 88.01 6293.43 1D-146 15May14 T3 MW 2300 2600 25.00 1200.00 10-146wp03(Plan:110-196) ceo-ac-es 19 10851.07 90.96 177.34 3852.56 -1408.93 6333.84 2.00 89.96 6333.84 1200.00 2752.53 119-146wpo3(Plan:10-106) MWD 20 11235.83 90.96 177.34 3846.13 -1793.22 6351.71 0.00 0.00 6351.71 2600 3000 1x00.00 275253 93-146,03(Plan:119-146) SOW 6-xK.e 21 11335.88 9068 179.32 3844.70 -1893.22 6354.63 200 97.94 6354.63 1D-146 15Ma 14 T4 MW 2752.53 425253 1D-146wp03(Plan:10-146) MWD y 2]52.53 7180.30 10-1wwpo3lPiare lD-106) MWDPF.-...-5C 22 16439.74 90.69 179.33 3783.70 6996.35 6414.70 0.00 49.34 6414.70 1D-146 15May14 T5 MW 3000 - 3400 7760.30 9260.30 D-146wp03(Plan:10-146) MWD I 7760.30 16439.74 0.146wp03 men:10.146) MWD.IF6-91tL0.2-SC 3400 3800 CASING DETAILS 3800 4200 w ND MD Name Size 4200 4600 2355.70 2752.53 13-3/8"x16" 10-3/4 3835.70 7780.30 9-5/8"x12-1/4" 7-5/8 3784.20 16397.98 4-1/2"x6-3/4" 4-1/2 4600 5000 5000 5400 0/360 ha41PB4 5400 5800 S P' 01,14:74,11:111111111671:;"A' 47`..41''°14"*;'4‘'744 � fl�®®jN4441 5800 7200 w �i� 1d� p �\ 7200 8500 . �* '4, 11a41P8 30/330s+s � � "� 30' -G�r ir. � •.• 885000 9900 ha142wpa¢ P 1��u3aI �t +��@Pvy�vt���\1 .i�� 1 00 11200 / r4fyjytllDn �1 31 1'-'-' r -124�A'+,C�����e� 4„0��fi',L=�, oft 45 /if//fm1 �G'1•a/s �4ll/ t 1415020"'087 v �� bt1�G�:QL 11200 12600 }1 /tj4mu 1A$a. a//11,��'��b�,a'wv���r� W®`ec as ♦e 0 I rn .sAs 14 . Ob O° t i1 4D 4.40 „-: t,�rj4➢i4 1e fl1'441`1.11. r`Nif. 1 /AI►1�1�/4-1�A 12600 13900 � ' �/�f aa4san Y \ a:��pqk`�la�,;��8 e`>w 1>''���da"�O�"� �il��/ SP r a „14 ,i,; 1411.1 ,-Iff 10sti �'t.'� ®� Qat tA, 13900 15300 "--..- .i y, y r ,N,' • AIntit` �a tm.fig,e ygtftek ;'.®'�\s 15300 16643 � �y�� ► �1//,Fe � 6'ia .r,��'i �iL�rs4��t1����®6 ��?V.L�1AIk� -60/300 lei 7 r�/iel; Pati w�_ eso+la�a 1=4Y @ ;� M 0 < �.>(�,'�3�Is :.are r 4,��p1BY a��®'ld � �gs��11a` 1`."1'�,'L�,\ 'y� ?1� �4 ..!.;kso 4 . .,.'n )iti8a �40,1'v = 1��'ii��+s6a.,1.. y `is �` 91 •5.444r 4ky i •411'1 \ e � ‘4 �y�ii�r�4 r . ,-. ®°I 41'''t -lei. k��1 . r , Hid tt� A• ` ,A, 1•`'0'1n'4..� 414 firg21'7 *till. ��fy1�L'i b.�� ®1 11 �. `a t \, , 1 • rh / // � yaae fq �'4 �\v t r lii 1 1 1� 9 O I< G \ 4' 1`1G10i � I��jji,,/'� r�,�/ror�,6l//!9 .� � COQ ���`d ��:-.� r� r1,�L� 1\ l; Brio � /l / v//,.�/i ®or® Aeiiirl id' , a► �e„�asorl tU41g6b 'eiC-NN'v 9 pr.i a44,�j4pi�lE /isi dA �e “iiily 1\V�-i;VP' ® 2""I' 1 081 1 .;_- , . . tiiv' till It '� ioi*I"Aki. '''4k 4- ',791114 iilr�'�l111 16kk h itti,- ,4 a ;v0 1,•,----o�"rto- ��r'd �I��.k 440111,�1�� , ': 4 .Al�PAt/,,ipp4A►.1 '* �1 01 ,iit tralk kV;*0,ti�� 1� 4171 IA14, , a)p�1 i�/11424°41144t t;1 '! I�,ry, 1 f 1� Y 41,♦ �. ..4,41! 617,4 10. Ilit . 1 ! r4�r,: 4r0'4,1'lb.i.i. l►k ,4.01/1\R� t yl1'1r1441: gr( ' �.�{,�aa1,1111474111,:� =41j11�' 14a��Iw.s,4 --.d.� �, K •1 `�>a�.:�'.A'RI RI.,11 �1ce -90Y 270 r q r• p^ t6,.2 '.rte .#4 v i m 4�? r F vczo 11 �1 � 90 9��1 1111 p ��Y 1 NVII 1' 44'04: -, .�.` aes lover g/ n l/ � 1 0143E .1 1!'�' �1�1ti41����IN 1;�� II p�\) �Wu�'� 1� `iritA \\\. ' a,iia�'' ij6•��✓�Ofy,�� 1H� �l ��1q o d�/1 a `N �p� r ar,44,,t o-V ' o,N \A 26 `®-' f it It, .' , t i� a143LaxP1,} `t.\„,,�0sivAi Q1,' 4uy.k 2Nd a,���0d ., I 14,04,,, / 1'« .0.Prk 9 p � 1.� � a� \ :�.,* fig/ / �i qui ,0 a 40 4060.. 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'_, 6 �� l i tT it•Il f/ 120 lila-ID-327111 (� Y ar Il[a`giiiVIM �,�;" WO11 ' t = 4!1,11 Lg 4 7Y 7„, relk, V,v� 049, : �� , f 14 11 1e;®�r ,ec1r.1;;41,40,, , t,`0_ .. ,,.�+__IIa141L1PB1 z 4 ,.- • rr �, y c e ,,4'.1..;!,':..:, gao 80.5- ` ,0111 1 1 a � I)tr \ . i. 2 s b 0 a 1 7.6 +4:.�r><'alli_ ,4 � r q,�.\� Esx�4p � _IiA,, a: '!r' >a 7-+ ,r °.\\ ho-141L1PB4 .�r,I�t\� ®G'1�� �� IiliIS �L �•.��„ ...,-.;..-e, ho-i4'tRe1 4V ��I '1 y ..:� `.w ..,.=a ��\ .�\ 9'►a'�° 4'd°t= '� 't`• all°0®®a•!'`'®11•�1��'1�� 111 Igo I • � . 1 t►• . , 4 ,. ' � ,dt� f ■� �11�� � h 1 1Io-145wp0.' 'k�t�ed, ,, !9'°44 C!;7,!-' 1?�fi,, li/i ;,4:,ltv q _�: I 0.141E -150/210 '` 111 _/jr 150 �Ia3auPB� �1�'_� i o,7, 4. fa �[1 o= -180/180 , IDa6wP4(Baked 11 D-36L2I • siral ...„_.. . .............. ..... . 4 . , .. 49- 0-22 Co,141, 20,1J-122,2002 V0 i- , #- , -tr am.lo9 tonIn ♦ ? 4 ro1.r -0P .34. J.122 Non+, 1420x0-612061 ♦ 91 O X460804 ♦ 161210240.,_.v,VI -e- o-135,1C 1/91,1 1351.81.1.135P81 VII $ , 20,11266 IO-126200.W4!IV9 $ , $ , -}- 1-144,,c-IM,10-,24 v9 $ 10127.20197,'6127 v2 -} 1 $ , 1rez+V4100001 -fr 90.10--,90.10-,9909 $ 1612&10.,08.10,x2 22 -j(- 1032,1062103x25 w $ 1042 ID42,1D-2240 j(- 065.1099100506 43- 10-12a,10-122.1012002 ♦ , $ ,042,042104221 VI � 095 1095 10.06 06 ♦ 13,0.131,ID10822 -fr t P81.10-321_1751 VI ♦ ,0421042,1,ID4101 VI -4. 097 -6- 1D -s- 1034 44. ,0-401P4a1.PM,0420175121 ♦ DM1004I�7 s -a. 1613x19„3,o2VV2 -j- 1 ♦ F 42.n.a,D14 ID.:0x420 ♦ 616,616,0-,912 ♦ mnx1D432,6135 vz R 43. D34,,D3a1,1D34��1 v4 ♦ P. num,Dl,t,o-lxwvlzw 1.133. $ 619,1019,16119 VV2 -$x" 6134'manV2 1 \ Fr 9 I I Plan t0-tu.Rn 1914312,943 .0200 -} .12 1.12 10-12V9 i- 1 1� 2� $ Plan.1.145,Plan 16145, 1.14.4,10-143L0,12705,ID4 - .12,612L1,1613.,V9 -� , r E.1,2 -!- 612,0101761,1012.2061 VO $ 161n,,D,n2P6+,mI -} 4 +Pu4n20.134z7,,r-,ave,0-!461720 v9 $ 16120,,0.1201.12022 ♦ 1.141.1014Inrm.10441APmw •4(- 10-37,161712,0371 W 4Ei. 10-142.pa 1D-146Jrilling Hazards Simmary 13.5" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight,use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti-Collsion with 1C-184 and 1C- Follow real time surveys closely. 1C-190 will be shut 190 in, and 1C-184 is shut in all ready Hole swabbing on trips Moderate Trip speeds, proper hole filling(use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Anti-Collision with 1D-41 Moderate Follow real time surveys very closely, stay in D sand while drilling lateral and we can avoid collision using geological certainty. Lost Circulation Moderate Reduced pump rates,mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds, proper hole filling(use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. ORIGINAttachment 2- 1D-146 Drilling Hazards Summary.doc 8/12/20148:45:13 AM 1 °-146 Schlumberger CemCADE Preliminary Job Design 10 3/4"Surface Casino (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Nabors 9ES Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2253' MD. Client:CPAI Revision Date:August 7,2014 Prepared by:Jenna Houston Location:Anchorage,AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -240 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11.00 ppg-1.91 ft3/100 lb sk email:jhouston2@slb.com 0.6382 ft3/ft x 80 x 1.0 (0% excess) = 52 ft3 < TOC at Surface 0.3637 ft3/ft x (1705-80) x 3.50 (250%excess) = 2069 ft3 0.3637 ft3/ft x (2253-1705) x 1.50 (50%excess) = 299 ft3 2069 ft3+52 ft3+299 ft3= 2420 ft3 2420 ft3/ 1.91 ft3/sk= 1268 sks(1275 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 1 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (2753-2253) x 1.50 (50%excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk= 195 sks Round up to 205 sks BHST= 67°F, Estimated BHCT =75°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,705'MD(1,655'TVD) Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) CW 100 7.0 50.0 7.1 7.1 MUDPUSH II 7.0 50.0 7.1 14.2 Pause 0.0 0.0 5.0 19.2 < Top of Tail at 11 ppg DeepCRETE 7.0 430.8 61.5 80 7 2,253'MD Lead Surface Tail 7.0 56.3 8.0 88.7 DeepCRETE Slurry Pause 0.0 0.0 5.0 93.7 Fresh Water 5.0 10.0 2.0 95.7 Pause 0.0 0.0 5.0 100.7 Mud 8.0 237.1 29.6 130.3 Mud 3.0 10.0 3.3 133.6 < 10 3/4",45.5#casing in 13.5"OH MUD REMOVAL Expected Mud Properties:9.4 ppg, Pv<20, Ty<20 TD at 2,753 MD Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21,Ty nu 20-25 (2,356'TVD) Centralizers: As per CPAI program. • Mark of Schlumberger ORIGINAL 1 D-146 Schlumberger CemCADE Preliminary Job Design 7 5/8" Intermediate (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nabors 9ES Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date:August 7,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds - 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@s1b.com 0.2148 ft3/ft x (7781'-4337') x 1.4 (40%excess) = 1036 ft3 Shoe Volume: 0.2578 ft3/ft x 80'x 1.00 (no excess) = 21 ft3 Totals: 1036 ft3+21 ft3= 1057 ft3 1057 ft3/ 1.16 ft3/sk= 912 sks(920 sks) BHST= 101°F, Estimated BHCT =82°F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.0 50.0 10.0 10.0 10 3/4"lb. ,45.5#casing Pause 0.0 0.0 5.0 15.0 at 2753'MD Tail Slurry 5.0 188.1 37.6 52.6 Pause 0.0 0.0 5.0 57.6 Fresh Water 5.0 10.0 2.0 59.6 Pause 0.0 0.0 5.0 64.6 Mud 6.0 333.6 55.6 120.2 Top of Tail at Mud 3.0 10.0 3.3 123.5 end of pumping < 4337'MD MUD REMOVAL Recommended Mud Properties:9.6 ppg, Py<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. 7 5/8",29.7# Spacer Properties:10.5 ppg MudPUSH* ll, Pv=25 -30, Ty=30 -40 in 9 7/8"hole Centralizers: As per CPAi program TD at-7781 'MD (3836'TVD) Mark of Schlumberger ORIGINAL • • --->� /1•'/g Y. V an-1 E iMvR A a� I a sir a 111 L .53i :' ,,ii ii, • • ..•N Il 8x I 0 m • Ul.] fn U 'F: I I o II i 0 r. " ° ".11 1 GL O V S 3 v • b U$ Et L Oc 3 '15 • VTa E ; • O € O U • a v S , S E v ' U at V ''1:`•g1,- it' F A u HI F0w o o 00 F Lam, 22 0 �,Ld r N oX79 a . , -0,SN� .a Nb^^p E 4 . C S F v 7,1 N U ConocoPhillips Draft Schematic 1D-146(Producer) 1D-146 Schemane{VPo3 Rev°crd Alaska 6/4 2014 ORIGINAL • • Bettis, Patricia K (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> P b oZI L/ -/3? Sent: Wednesday, October 01, 2014 4:20 PM To: Bettis, Patricia K (DOA) Cc: Jolley, Liz C; Hallford, Kelsey Subject: 1D Permits to Drill Attachments: Permit to Drill 1D-142.pdf; 1D-142wp06 -Plan Summary.pdf; Permit to Drill 1D-143 L1.pdf; Permit to Drill 1D-143 L2.pdf; Permit to Drill 1D-143 L3.pdf; Permit to Drill 1D-143.pdf; 1D-143L1wp13 PlanSummary.pdf; 1D-143L2wp13 PlanSummary.pdf; 1D-143L3wp13 PlanSummary.pdf; 1D-143wp13 PlanSummary.pdf; Permit to Drill 1D-145.pdf; 1D-145wp06- Plan Summary.pdf; Permit to Drill 1D-146.pdf; 1D-146wp04- Plan Summary.pdf Patricia, as we discussed on the phone,the 1D wells ended up having their surface locations shifted by—17'. Attached please find the updated 10-401's for each of the wells as well as the updated directional plans with the new surface coordinates. If you have any questions or require any further information please let me know. Thanks David 1 • • ly�c&. l� - 4co Bettis, Patricia K (DOA) PTI fly From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Thursday, September 18, 2014 2:20 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 1D-145: Permit to Drill Application Morning Patricia, here are the logging program for each of the 1D Wells: 1D-142 Surface—Gamma, Resistivity, Density, Neutron Intermediate—Gamma, Resistivity Lateral—Gamma, Resistivity, sonic (for cement top evaluation) and periscope 1D-143 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, density, neutron Lateral x 4—Gamma, Resistivity and periscope 1D-146 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity Lateral x 4—Gamma, Resistivity and periscope 1D-145 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, Lateral x 4—Gamma, Resistivity and periscope Please let me know if you need anything else. Thanks David From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, September 18, 2014 9:12 AM To: Lee, David L Subject: [EXTERNAL]KRU 1D-145: Permit to Drill Application Good morning David, Please submit the logging program for each section of the proposed well. Thank you, Patricia 1 t 4 • • Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • TRANSMITTAL LETTER CHECKLIST WELL NAME: KRLL - /y (o PTD: 0219 - �3y /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: I<t, < &f POOL: I\�� RI.ViLkri I &,.S)< -cc-/h v' l 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,n also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 0 0 ❑❑ �o , , , , N b y. L N C m, Q U, 0. , , L N' C, Z `O • L a> a F-, O m ' O O c' , a) , , , , : E O o N ° _0' o , , , , a o' P2 CO ca 2 J W L' a , c. rn 3, O c ' N, O o; v; , 2 c, , c •= o, o ° -co, oi ' o aa , � Oa _3 1, 1- oJp J E' : , : : a E, 4 _, a Y m _0. �,Q, m 4 c., , (/), a o « a) • Y '0 ca oa 0. 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