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Home My WebLink About214-082C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-03-03_22641_KRU_3Q-14A_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22641 KRU 3Q-14A 50-029-21665-01 LeakPoint Survey 03-Mar-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 214-082 T40203 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 13:58:09 -09'00' Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 3B-04 50-029-21323-00 909740412 Kuparuk River Plug Setting Record Field- Final 3-Jan-25 0 12 3H-21 50-103-20094-00 909740216 Kuparuk River Multi Finger Caliper Field & Processed 5-Jan-25 0 13 3H-21 50-103-20094-00 909740216 Kuparuk River Plug Setting Record Field- Final 6-Jan-25 0 14 3H-33A 50-103-20578-01 909740217 Kuparuk River Plug Setting Record Field- Final 29-Dec-24 0 15 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 2-Nov-24 0 16 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 3-Nov-24 0 17 3K-24 50-029-22935-00 909619038 Kuparuk River Multi Finger Caliper Field & Processed 7-Nov-24 0 18 3K-24 50-029-22935-00 909619503 Kuparuk River Plug Setting Record Field- Final 30-Oct-24 0 19 3Q-14A 50-029-21665-01 909740219 Kuparuk River Leak Detect Log Field- Final 8-Dec-24 0 110 3Q-14A 50-029-21665-01 909740219 Kuparuk River Multi Finger Caliper Field & Processed 9-Dec-24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40008T40009T40009T40010T40011T40011T40012T40012185-061188-008209-103189-025198-249214-082T40013T400131/23/202593Q-14A50-029-21665-01909740219Kuparuk RiverLeak Detect LogField- Final8-Dec-2401103Q-14A50-029-21665-01909740219Kuparuk RiverMulti Finger CaliperField & Processed9-Dec-2401198 249214-082Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:18:26 -09'00' 2 140 82 32005 -CASE _ I HOLED Well Loq Transmittal To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 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: RECEIVED READ Cased Hole, Inc. JAN 3 1 2020 Attn: Diane Williams 4141 Suit B Street AOGCC Anchorage, AK 99503 Diane.WilliamsO-readcasedhole.com 26 -Jan -20 30-14A 1 Report / CD 50-029-21665-01 Date : 0 1 N ` READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGEO-READCASEDHOLE.COM WEBSITE: WWW.READCASEDHOLE.COM httpsl/readcasedhole-mysharepoint. com/personal/di ane_williams_readcasedhole_com/Documents/D Drive/Achives/MasterTemplateFiles/Templates/Distribution/Transmittal Sheets/ConocoPhillips_Transmit.docx 32005 CASED HOLE Company: ConocoPhillips Alaska, Inc. Log Date: January 26, 2020 Log No.: 14421 Run No.: 2 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE 8RD MOD Pipe Use: Tubing 214082 Memory Multi -Finger Caliper Log Results Summary Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Inspection Type : Restriction Inspection COMMENTS: This caliper data is tied into the top of GLM 5 at 7,414 feet. 3Q -14A Kuaruk Alaska 50-029-21665-01 Surface 8,027 Ft. (MD) This log was run to assess the condition of the tubing with respect to I.D. restrictions due to suspected scale build-up and how recorded GR correlates to the scale to determine if the GR tool can accurately locate scale in the wellbore and determine where the scale is most concentrated. The caliper recordings indicate the start of scale texture at --900 feet, with light to moderate scale increasing in severity with depth from —2,900 feet to —7,100 feet, and heavy scale from —7,950 feet to 8,027 feet (end of log). The GR signature seems to correlate with the amount of scale build-up as highlighted in the attached caliper log plot. The caliper recordings indicate the 3.5 inch tubing logged appears to range from good to poor condition with respect to internal corrosive and mechanical damage, with wall penetrations ranging from 20% to 44% wall thickness in 62 of the 256 joints logged. Recorded damage appears as isolated pitting, a line of pits, and line corrosion. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. The caliper recordings indicate light to heavy scale, increasing in severity with depth from --900 feet to 8,027 feet (end of log), restricting the I.D. to 2.28 inches at 8,023 feet. The presence of heavy scale may mask additional damage to the inside of the tubing. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the tubing logged is included in this report. This is the second time a READ caliper has been run in this well, and the second time the 3.5 inch tubing has been logged from 7,706 feet to 8,131 feet. A visual inspection of the repeat logged interval indicates an increase in scale build-up during the time between logs. Due to the short recorded interval in the previous log, no comparison graph is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits 44 97 3,041 Ft. (MD) Isolated Pitting 37 92 2,911 Ft. (MD) Line of Pits 35 96 3,031 Ft. (MD) Line Corrosion 35 94 2,972 Ft. (MD) Line Corrosion 34 86 2,694 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the tubing logged. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica0readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MAXIMUM RECORDED ID RESTRICTIONS: Heavy Scale 2.28 inches 254.1 8,023 Ft. (MD) Heavy Scale 2.30 inches 254 8,015 Ft. (MD) Heavy Scale 2.41 inches 253 7,985 Ft. (MD) Scale 2.56 inches 252 7,933 Ft. (MD) Scale 2.59 inches 251 7,922 Ft. (MD) C. Goerdt C. Waldrop S. Ferguson Field E�neer(s Analysts) Alitriesslcss READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA- NorthAmerica0)readcasedhole. com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 m NJ :X k:1 it I I K? 451 `� �: f: tl ii iF I f 4-'� Vill WANWIMIRIM!S4 S. kftr-w--AWJAl9'JKM �3�;� i��'f Tii� �. i'� F� f .i 1 � r 1��T I` ! ! LIT M P31. .11 Lit �11 at fit. Af fjt Eli WIN .L. .., I +r' Hk tit Fit W 'it. i; rv ] IKE ., z � t WE It RL �: t F E low lmmmmmma 7 it a�I�� IV. _MINOMENIM1111 !!MR `> E# r A+ltMMM� 57 7Gp JMmmMM1101mli 311MISMEM111111111 MA wil ir41 it tt io- Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (18.8' - 8,027.0') Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: January 26, 2020 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 254.2 0 Bottom of Survey = 254.2 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 50 Damage Profile (% wall) /Tool Deviation (degrees) 24 778 1,561 2,343 3,131 _ 3,918 z a a� O 4,708 5,492 6,283 7,071 7,860 8,024 100 Minimum Diameter Profile Survey Date: CASED Tool Type: UW MFC 24 No. 211387 HOLE Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Minimum Diameter Profile Survey Date: January 26, 2020 Tool Type: UW MFC 24 No. 211387 Tool Size: 1.69 inches Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 0.1 10 19 29 39 49 59 69 79 89 98 108 118 E Z 128 S 138 147 157 167 177 186 196 206 215 225 235 244 254 19 305 589 904 1,216 1,529 1,844 2,155 2,468 2,779 3,069 3,382 3,697 4,012 4,323 4,614 4,927 5,241 5,555 5,844 5,159 5,472 5,757 7,071 7,382 7,672 7,985 CASE® HOLE Body Region Analysis Well: 3Q -14A Survey Date: January 26, 2020 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ARD MOD 2.992 in. 19 ft. 8,027 ft. Penetration (% wall) Damage Profile (% wall) 200 Penetration body Metal loss body 0 50 100 0.1 150 50 0 0 to 20 to 40 to over 20% 40% 85% 85% GLM 1 (1:30) Number of joints anazed (total = 256) 194 61 1 0 Damage Configuration (body) 100 GLM 2 (2:00) �_ � -- GLM 3 (1:00) 4U — - — GLM 4 (11:00) 20 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total= 13 1) L 45 1 85 0 0 GLM 5 (1:00) GLKA C Bottom of Survey = 254.2 49 98 I i 147 f ii I I 196 I 244 I I Bottom of Survey = 254.2 CASED HOLE Well: 3Q -1 4A Field: Kuparuk Company: ConocoPhi►lips Alaska, Inc. Joint Tabulation Sheet Survey Date: January 26, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 19 ft Bottom Dept 8,027 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 19 0 0.04 15 5 2.95 Pup Shallow Line of Pits. 1 24 0 0.03 10 1 2.92 2 55 0 0.07 28 13 2.91 Isolated Pitting. 3 86 0 0.03 13 2 2.93 4 117 0 0.03 11 4 2.93 5 149 1 0.04 0.03 13 4 2.92 6 180 0 0.03 10 2 2.93 7 212 0 0.03 10 3 2.90 8 243 0 0.03 11 3 2.92 9 274 0 0.02 9 2 2.92 10 305 0 0.03 11 3 2.93 11 337 0 0.03 11 4 2.91 12 368 0 0.03 10 2 2.91 13 400 0 0.03 11 2 2.90 14 431 0 0.03 12 3 2.91 15 462 0 0.03 11 3 2.92 15.1 494 0 0 0 0 2.80 3.5" Camco DS Ni le 16 495 0 0.03 12 3 2.93 17 526 0 0.03 11 3 2.93 18 558 0 0.03 11 2 2.92 19 589 0 0.03 11 3 2.92 20 621 0 0.03 11 2 2.92 21 652 0 0.03 11 2 2.92 22 684 0 0.03 13 3 2.93 23 715 0 0.02 9 2 2.91 24 747 0 0.03 13 2 2.90 25 778 0 0.04 17 2 2.91 Shallow Pitting. 26 809 0 0.03 11 2 2.92 27 841 0 0.03 12 _ 2 2.91 28 872 0 0.04 14 2 2.90 29 904 ! 0 0.04 14 3 2.91 Lt, Scale. 30 935 0 0.03 10 1 2.92 Lt. Scale. 31 966 0 0.03 11 2 2.91 Lt. Scale. 32 998 0 0.03 12 2 2.90 Lt. Scale. 33 1028 0 0.02 9 1 2.89 Lt. Scale. 34 1060 0 0.03 10 1 2.90 Lt. Scale. 35 1091 0 0.04 16 5 2.92 Shallow Pitting. Lt Scale. 36 1123 0 0.03 11 2 2.91 Lt. Scale. 37 1154 0 0.03 12 2 2.91 Lt. Scale. 38 1186 0 0.02 9 1 2.90 Lt. Scale. 39 1216 0 0.03 13 2 2.91 Lt. Scale. 40 1248 0 0.03 12 2 2.91 Lt. Scale. 41 1279 0 0.03 12 2 2.92 Lt. Scale. 42 1311 0 0.03 12 2 2.91 Lt. Scale. 43 1342 0 0.03 12 2 2.90 Lt. Scale. 44 1372 0 0.04 15 2 2.92 Shallow Pitting. Lt Scale. 45 1404 0 0.04 15 2 2.91 Shallow Pitting. Lt Scale. 46 1435 0.04 0.04 16 2 2.92 Shallow Pitting. Lt Scale. 47 1467 0 0.05 19 3 2.92 Shallow Line of Pits. Lt. Scale. 48 1498 0 1 0.03 13 2 2.90 Lt. Scale. Penetration Body Metal Loss Body Page 1 CASED HOLE Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: January 26, 2020 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 19 ft 8,027 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 49 1529 0 0.05 20 3 2.92 Line of Pits. Lt. Scale. 50 1561 0 0.05 19 2 2.92 Shallow Pitting. Lt Scale. 51 1593 0 0.04 17 2 2.94 Shallow Line of Pits. 52 1624 0 0.05 19 4 2.94 Shallow Pitting. 53 1656 0.04 0.04 17 3 2.92 Shallow Line of Pits. Lt. Scale. 54 1687 0 1 0.04 17 1 3 2.92 Shallow Line of Pits. Lt. Scale. 55 1719 0 0.06 22 3 2.94 Isolated Pitting. 56 1750 0 0.05 19 3 2.93 Shallow Line of Pits. Lt. Scale. 57 1782 0 0.05 19 2 2.93 Shallow Pitting. Lt Scale. 58 1813 0.04 0.06 22 4 2.92 Isolated Pitting. Lt Scale. 59 1844 0.04 0.05 18 2 2.92 Shallow Line of Pits. Lt. Scale. 60 1876 0.04 0.05 19 4 2.93 Shallow Line of Pits. Lt. Scale. 61 1905 0 0.05 18 4 2.94 Shallow Line of Pits. 62 1937 0 0.05 20 4 2.93 Isolated Pitting. Lt Scale. 63 1966 0 0.06 24 5 2.95 Line of Pits. 64 1998 0.05 0.04 17 2 2.92 Shallow Line of Pits. Lt. Scale. 65 2029 0.05 0.05 19 4 2.92 Shallow Line of Pits. Lt. Scale. 66 2061 0.04 0.04 17 3 2.93 Shallow Line of Pits. 67 2092 0 0.05 19 3 2.93 Shallow Line of Pits. Lt. Scale. 68 2124 0 0.05 21 4 2.93 1 Line of Pits. Lt. Scale. 69 2155 0 0.05 19 4 2.93 1 Shallow Line of Pits. Lt. Scale. 70 2186 0 0.05 21 4 2.93 Line of Pits. Lt. Scale. 71 2217 0 0.05 20 4 2.92 Line of Pits. Lt. Scale. 72 2249 0 0.04 17 2 2.92 Shallow Pitting. Lt Scale. 73 2280 0 0.05 21 4 2.93 Line of Pits. 74 2312 0.04 0.06 25 5 2.93 Isolated Pitting. Lt Scale. 75 2343 0.04 0.07 26 1 6 2.93 Line of Pits. Lt. Scale. 76 2374 0.04 0.05 20 4 2.92 Line of Pits. Lt. Scale. 77 2405 0.04 0.06 25 6 2.92 Line Corrosion. Lt. Scale. 78 2437 0.05 0.07 26 6 2.92 Isolated Pitting. Lt Scale. 79 2468 0.04 0.05 21 5 2.92 Line Corrosion. Lt. Scale. 80 2500 0 0.08 30 6 2.93 Line Corrosion. 81 2531 0.05 0.06 22 6 2.93 Line Corrosion. Lt. Scale. 82 2562 0.04 0.07 27 6 2.92 Isolated Pitting. Lt Scale. 83 2593 0 0.08 31 7 2.93 Isolated Pitting. Lt Scale. 84 2625 0 0.08 33 5 2.92 Line of Pits. Lt. Scale. 85 2656 0 0.06 24 7 2.90 Isolated Pitting. Lt Scale. 86 2686 0 0.09 34 6 2.90 Line Corrosion. Lt. Scale. 87 2718 0 0.08 30 7 2.91 Isolated Pitting. Lt Scale. 88 2748 0.05 0.06 1 25 6 2.92 Line of Pits. Lt. Scale. 89 2779 0.07 0.06 24 6 2.92 Line of Pits. Lt. Scale. 90 2811 0 0.06 22 4 2.91 Line of Pits. Lt. Scale. 91 2842 0 0.06 23 6 2.90 Isolated Pitting. Lt Scale. 91.1 2874 0 0 0 0 2.90 GLM 1 Latch ® 1:30 92 2880 0.07 0.09 37 6 2.92 Isolated Pitting. Lt Scale. 93 1 2912 0.07 0.08 33 5 2.90 Line of Pits. Lt. Scale. 94 2943 0.06 0.09 35 6 2.91 Line Corrosion. Lt. Scale. 95 2975 0 0.08 30 5 2.91 Line of Pits. Lt. Scale. 96 3006 0.05 0.09 35 6 2.90 Line of Pits. Lt. Scale. 97 3038 0.06 0.11 44 6 2.91 Line of Pits. Lt. Scale. Penetration Body Metal Loss Body Page 2 CASED HOLE Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: January 26, 2020 Analyst: Waldrop Pipe Description - 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall 2.992 in. 0.254 in. Top Depth Bottom Depth 19 ft 8,027 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 98 3069 0.05 0.08 32 5 2.88 Isolated Pitting. Lt Scale. 99 3101 0 0.07 26 5 2.90 Isolated Pitting. Lt Scale. 100 3131 0 0.06 24 4 2.90 Line of Pits. Lt. Scale. 101 3162 0.04 0.04 17 3 2.91 Shallow Line of Pits. Lt. Scale. 102 3193 0.04 0.06 22 4 2.63 Isolated Pitting. Scale. 103 3225 0.04 0.06 22 4 2.89 Line of Pits. Lt. Scale. 104 3256 0 0.07 26 7 2.91 Corrosion. Lt. Scale. 105 3289 0 0.06 22 5 2.90 Line of Pits. Lt. Scale. 106 3320 0.04 0.08 31 6 2.90 Line of Pits. Lt. Scale. 107 3352 0.04 0.05 20 4 2.89 Line of Pits. Lt. Scale. 108 3382 0.05 1 0.07 26 5 2.89 Line of Pits. Lt. Scale. 109 3413 0.05 1 0.08 30 5 2.90 Line of Pits. Lt. Scale. 110 3445 0.11 1 0.08 30 5 2.90 Isolated Pitting. Lt Scale. 111 3477 0 0.05 18 3 2.89 Shallow Line of Pits. Lt. Scale. 112 3508 0 0.04 17 3 2.89 Shallow Line of Pits. Lt. Scale. 113 3540 0.05 0.07 28 6 2.91 Line of Pits. Lt. Scale. 114 3571 0.05 0.05 19 2 2.88 Shallow Pitting. Lt Scale. 115 3603 0.06 0.06 25 4 2.90 Line of Pits. Lt. Scale. _116 3634 0.07 0.06 25 3 2.90 Isolated Pitting. Lt Scale. 117 3665 0.04 0.08 32 5 2.89 1 Line of Pits. Lt. Scale. 118 3697 0.05 0.05 19 4 2.89 Shallow Line of Pits. Lt. Scale. 119 3729 0 0.08 31 1 2 2.89 Line of Pits. Lt. Scale. 120 3760 0.04 0.06 23 3 2.90 Line of Pits. Lt. Scale. 121 3792 0.05 0.04 17 3 2.89 Shallow Pitting. Lt Scale. 122 3823 0 0.04 17 2 2.88 Shallow Line of Pits. Lt. Scale. 123 3855 0 0.05 19 1 2.88 Shallow Pitting. Lt Scale. 124 3886 0 0.04 15 2 2.89 Shallow Line of Pits. Lt. Scale. 125 3918 0 0.05 18 2 2.88 Shallow Line of Pits. Lt. Scale. 126 3949 0.04 0.04 15 2 2.88 Shallow Line of Pits. Lt. Scale. 127 3981 0 0.05 19 1 2 2.88 Shallow Line of Pits. Lt. Scale. 128 4012 0 0.04 16 4 2.89 Shallow Line of Pits. Lt. Scale. 129 4042 0.04 0.06 23 5 2.90 Line Corrosion. Lt. Scale. 130 4074 0 0.05 18 2 2.89 Shallow Line of Pits. Lt. Scale. 131 4105 0 0.03 13 1 2.89 1 Lt. Scale. 132 4137 0 0.03 13 2 2.89 Lt. Scale. 133 4168 0.04 0.05 18 4 2.90 Shallow Line of Pits. Lt. Scale. 134 4200 0.04 0.03 13 3 2.90 Lt. Scale. 135 4230 0 0.04 16 3 2.89 Shallow Line of Pits. Lt. Scale. 136 4262 0.04 0.06 23 5 2.90 Line of Pits. Lt. Scale. 137 4292 0 0.05 20 3 2.89 Line of Pits. Lt. Scale. 138 4323 0 0.06 22 4 2.90 Line of Pits. Lt. Scale. 139 4355 0.04 0.04 16 3 2.89 Shallow Line of Pits. Lt. Scale. 140 4386 0 0.05 18 3 2.90 1 Shallow Pitting. Lt Scale. 140.1 4418 0 0 0 0 2.84 GLM 2 Latch @ 2:00 141 4424 0 0.05 19 4 2.91 Shallow Line of Pits. Lt. Scale. 142 4456 0 0.06 22 3 2.89 Isolated Pitting. Lt Scale. 143 4488 0.04 0.06 25 4 2.88 Line of Pits. Lt. Scale. 144 4519 0.04 0.05 19 2 2.88 Shallow Line of Pits. Lt. Scale. 145 4551 0 0.04 17 2 2.88 Shallow Line of Pits. Lt. Scale. 146 4582 0.04 0.04 17 2 2.89 1 Shallow Line of Pits. Lt. Scale. 'Penetration Body Metal Loss Body Page 3 CASED HOLE Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tub Joint Tabulation Sheet Survey Date: January 26, 2020 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 19 ft 8,027 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 147 4614 0 0.04 17 3 2.88 Shallow Line of Pits. Lt. Scale. 148 4645 0 0.05 20 2 2.89 Isolated Pitting. Lt Scale. 149 4677 0 0.05 20 3 2.89 Line of Pits. Lt. Scale. 150 4708 0 0.04 15 2 2.88 Shallow Line of Pits. Lt. Scale. 151 4740 0 0.03 13 2 2.88 Lt. Scale. 152 4771 0.04 0.05 19 2 2.87 Shallow Line of Pits. Lt. Scale. 153 4803 0 0.06 22 2 2.87 Isolated Pitting. Lt Scale. 154 4833 0 0.05 19 2 2.89 Shallow Line of Pits. Lt. Scale. 155 4865 0.06 0.04 17 2 2.89 Shallow Line of Pits. Lt. Scale. 156 4896 0 0.03 13 1 2.88 Lt. Scale. 157 4927 0 0.05 19 2 2.89 Shallow Line of Pits. Lt. Scale. 158 4958 0.05 0.04 16 1 2.88 Shallow Line of Pits. Lt. Scale. 159 4990 0 0.03 12 0 2.88 Lt. Scale. 160 5021 0 0.03 11 0 2.87 Lt. Scale. 161 5053 0 0.03 12 1 2.88 Lt. Scale. 162 5084 0 0.03 10 0 2.87 Lt. Scale. 163 5116 0 0.03 12 1 2.87 Lt. Scale. 164 5147 0 0.03 12 0 2.89 Lt. Scale. 165 5178 0 0.03 11 0 2.86 Lt. Scale. 166 5210 0 0.03 13 1 2.86 Lt. Scale. _ 167 5241 0 0.03 13 2 2.88 Lt. Scale. 168 5272 0 0.04 16 0 2.87Shallow Pitting. Lt Scale. 169 5304 I 0 0.02 6 0 2.87 Lt. Scale. 170 5336 0 0.03 11 0 2.87 1 Lt. Scale. 171 5367 0 0.04 15 2 2.88 Shallow Line of Pits. Lt. Scale. 172 5399 0 0.03 11 0 2.89 Lt. Scale. 173 5429 0 0.02 9 0 2.88 Lt. Scale. 174 5461 0 0.03 12 1 2.88 Lt. Scale. 175 5492 0 0.04 16 0 2.89 Shallow Pitting. Lt Scale. 176 5524 0 0.03 13 1 2.87 Lt. Scale. 177 5555 0 0.04 15 1 2.87 Shallow Pitting. Lt Scale. 178 5586 0 0.03 10 0 2.86 Lt. Scale. 179 5618 0 0.03 12 1 2.87 Lt. Scale. 179.1 5649 0 0 0 0 2.85 GLM 3 Latch @ 1:00 180 5656 0 0.05 18 2 2.87 1 Shallow Pitting. Lt Scale. 181 5687 0 0.04 17 1 2.88 Shallow Pitting. Lt Scale. 182 5718 0 0.04 16 2 2.88 Shallow Line of Pits. Lt. Scale. 183 5750 0 0.03 13 1 2.87 Lt. Scale. 184 5781 0 0.03 13 1 2.87 Lt. Scale. 185 5813 0 0.04 16 1 1 2.87 Shallow Line of Pits. Lt. Scale. 186 5844 0 0.03 11 0 2.86 Lt. Scale. 187 5875 0 0.03 10 0 2.88 Lt. Scale. 188 5907 0 0.03 10 0 2.88 Lt. Scale. 189 5939 0 0.03 10 0 2.87 Lt. Scale. 190 5970 0 0.03 11 1 2.85 Lt. Scale. 191 6002 0 0.03 11 1 2.87 Lt. Scale. 192 6033 0 0.03 12 1 2.87 Lt. Scale. 193 6065 0 0.03 13 1 2.88 Lt. Scale. 194 6096 0.04 0.05 18 2 2.87 Shallow Pitting. Lt Scale. 195 6128 0 0.04 16 1 2.88 Shallow Line of Pits. Lt. Scale. Penetration Body Metal Loss Body Page 4 CASED HOLE Joint Tabulation Sheet Well: 3Q -14A Survey Date: January 26, 2020 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 19 ft 8,027 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 196 6159 0 0.04 17 2 2.87 Shallow Line of Pits. Lt. Scale. 197 6191 0 0.03 13 0 2.87 Lt. Scale. 198 6221 0 0.03 13 0 2.86 Lt. Scale. 199 6252 0 0.04 16 2 2.86 Shallow Pitting. Lt Scale. 200 6283 0 0.03 13 1 2.86 Lt. Scale. 201 6315 0 0.03 12 2 2.87 Lt, Scale. 202 6346 0 0.04 15 1 2.86 Shallow Pitting. Lt Scale. 203 6378 0 0.03 11 0 2.86 Lt. Scale. 204 6409 0 0.04 16 0 2.86 Shallow Pitting. Lt Scale. 205 6440 0 0.03 11 0 2.86 1 Lt. Scale. 206 6472 0 0.03 12 1 2.86 Lt. Scale. 207 6503 0 0.03 12 0 2.86 Lt. Scale. 208 6534 0 0.03 13 0 2.86 Lt. Scale. 209 6565 0 0.03 12 1 2.85 Lt. Scale. 209.1 6597 0 0 0 0 2.81 GLM 4 Latch @ 11:00 210 6603 0 0.03 11 0 2.86 Lt. Scale. 211 6635 0 0.03 11 0 2.85 Lt. Scale. 212 6666 0 0.03 11 0 2.84 Lt. Scale. 213 6696 0 0.03_ 11 0 2.86 Lt. Scale. 214 6727 0 0.03 10 1 0 2.87 1 Lt. Scale. 215 6757 0 0.03 10 0 2.85 Lt. Scale. 216 6789 0 0.03 12 0 2.84 Lt. Scale. 217 6820 0 0.02 9 0 2.85 Lt. Scale. 218 6852 0 0.03 11 1 2.81 Lt. Scale. 219 6883 0 0.03 12 0 2.85 Lt. Scale. 220 6915 0 0.03 11 0 2.86 Lt. Scale. 221 6946 0 0.04 15 1 2.84 Shallow Pitting. Lt Scale. 222 6978 0 0.03 12 0 2.86 Lt. Scale. 223 7009 0 0.04 16 2 2.85 Shallow Line of Pits. Lt. Scale. 224 7041 0 0.03 12 0 2.85 Lt. Scale. 225 7071 0 0.01 5 0 2.84 Lt. Scale. 226 7103 0 0.03 13 1 2.83 Lt. Scale. 227 7133 0 0.03 11 0 2.84 Lt. Scale. 228 7164 0 0.03 10 0 2.78 Scale. 229 7195 0 0.02 9 0 2.82 Lt. Scale. 230 7226 0 0.04 15 0 2.82 Shallow Pitting. Lt Scale. 231 7258 0 0.02 7 0 2.80 Scale. 232 7289 0 0.02 6 0 2.77 Scale. 233 7319 0 0.01 4 0 2.75 Scale. 234 7351 0 0.00 0 0 2.76 Scale. 235 7382 0 0.00 2 0 2.75 Scale. 235.1 7414 0 0 0 0 2.71 GLM 5 Latch ® 1:00 236 7420 0 0 0 0 2.72 1 Scale. 237 7452 0 0.01 4 0 2.72 Scale. 238 7483 0 0 0 0 2.69 Scale. 239 7515 0 0 0 0 2.70 Scale. 240 7545 0 0.01 4 0 2.70 Scale. 241 7577 0 0 0 0 2.70 Scale. 242 7608 0 0.01 1 3 0 2.65 Scale. 243 7640 0 0 0 0 1 2.66 Scale. Penetration Body Metal Loss Body Page 5 i Well: Field: Company: CASED HOLE 3Q -14A Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: January 26, 2020 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth BotomDepth 2.992 in. 0.254 in. 19 ft 8,027 ft. Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 244 7672 0 0.00 2 0 2.65 Scale. 245 7703 0 0.00 2 0 2.64 Scale. 246 7734 0 0 0 0 2.62 Scale. 247 7766 0 0.05 20 0 2.66 Isolated Pitting. Scale. 248 7797 0 0 0 1 0 2.61 Scale. 249 7828 0 0.00 2 0 2.63 Scale. 250 7860 0 0 0 0 2.60 Scale. 251 7892 0 0 0 0 2.59 Scale. 252 7923 0 0.01 4 0 2.56 Scale. 253 7954 0 0 0 0 2.41 Heavy Scale. 254 7985 0 0 0 0 2.30 Heavy Scale. 254.1 8016 0 0 0 0 2.28 Pup Heaw Scale. 254.2 8024 0 0 0 0 2.34 GLM 6 Latch Position N/A) Penetration Body Metal Loss Body Page 6 CASED Cross-sectional Illustration HOLE Well: 3Q -14A Survey Date: January 26, 2020 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing:_ 3.5 in. 9.3 ppf L 80 EUE 8RD MOD Analyst: Waldrop Cross Section for Joint 97 at depth 3,040.690 ft. Tool speed = 50 ft/min Nominal ID = 2.992 in. Nominal OD = 3.5 in. Remaining wall area = 94% Tool deviation = 41 ° Finger = 18 Penetration = 0.115 in. Line of Pits 0.11 in. = 44% Wall Penetration HIGH SIDE = UP Cross Section for Joint 92 at depth 2,911.100 ft. Tool speed = 49 ft/min Nominal ID = 2.992 in. Nominal OD = 3.5 in. Remaining wall area = 94% Tool deviation = 41 ° Finger = 17 Penetration = 0.093 in. Isolated Pitting 0.93 in. = 37% Wall Penetration HIGH SIDE = UP -- _ HOLED Cross-sectional Illustration Well: 3Q -14A Survey Date: January 26, 2020 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing:__ 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: _ Waldrop Cross Section for Joint 92 at depth 2,911.100 ft. Tool speed = 49 ft/min Nominal ID = 2.992 in. Nominal OD = 3.5 in. Remaining wall area = 94% Tool deviation = 41 ° Finger = 17 Penetration = 0.093 in. Isolated Pitting 0.93 in. = 37% Wall Penetration HIGH SIDE = UP CASED HOLE Cross-sectional Illustration Well: 3Q -14A Survey Date: January 26, 2020 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing:__ 3.5 in. 9.3ppf L-80 EUE 8RD MOD Analyst:_ _ Waldrop__ _ Cross Section for Joint 254.1 at depth 8,022.850 ft. Tool speed = 54 ft/min Nominal ID = 2.992 in. Nominal OD = 3.5 in. Remaining wall area= 100% Tool deviation = 38° Minimum I.D. = 2.276 in. Heavy Scale Minimum I.D. = 2.28 in. HIGH SIDE = UP CASED HOLE Well: 3Q -14A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Cross-sectional Illustration Survey Date: January 26, 2020 Tool Type: UW MFC 24 No. 211387 Tool Size: 1.69 inches No. of Fingers: 24 Analvst: Waldron Cross Section for Joint 254 at depth 8,015.480 ft. Tool speed = 55 ft/min Nominal ID = 2.992 in. Nominal OD = 3.5 in. Remaining wall area = 100% Tool deviation = 38° Minimum I.D. = 2.300 in. Heavy Scale Minimum I.D. = 2.30 in. HIGH SIDE = UP KUP PROD WEUXME 3Q-14A VVEL LSME 3Q-14A _ ConocoPhiilips /ttEri74F6es wTD 110YYmIeeM1yea ADYM ,. Yawl An 9r 141L4a nl�ftill3 l'u: Pr1008l KLOrARc3(q'.Ji L'rgT 9702Y215fiW1 PROD 70081 6,440.67 t1399.0 caslw xia Miert are Aewalrm elY are an4]N lq ail neleer oeee 340 12±36L'20ia I- We, 4251 12.'UI'066 10-+a iW7F1EAa�aw last Tap w.l� �d.o.er.:r4a; wYa irA a.pe mw w mda w.mv. Lea Ym r LAY r.9 bud e,ca+n 10'14.2014 30-14A »FYlir rWiaCR 31 Last Rw Reason w..oirle,r ala or. xlrmn tl>t YM ny Fier Reitan: OLD trAsal 3lLi1979 30.14.4 IW GplIf1LC'f(1"R ]T biwJ eoL� aeewiam w Fq o lsl Tap M-1 M 9.pn PR41 MOAN y fl GreM iw IT.aW uattc aic UMFACE OSS 6.'77' 370 4,37.2 3,747:0 36:00 J-66 657_6 Ce»ea--pam WIrl niq I-I-I I M0". 1-1 Ma.M►Srwi... Maas ir._a.r. Tw m.m Well'-: ]eM ri1NOOWA 7 628 9-1160 8.2t7 9 6,443.4 Gayy anecr4am WIM o1M Tap lnanl MGFW ITamI Ma�fn (iV9t... YILLs {I�Orde TSF T+wa W'a lr; a.m 1 LAEF A 2 319 1.06 10034.7 17,393.0 6,454.3 4.T7 lE0 8TL Linn mita d Tep IiFLYI Tq ITMOl flag TapMl'1 la o. Gam 1x1 alwe-r. o+,nr. t0,7t0.7 I 6424.5-Mflta..LSf C,'ALUKNUMBI -ET 11000 T Well-: s,ana: Tabby 0lecrlplm arra Ya.. ro Ird r4c®ca M arF1n In.. M Oep4 Fix► s.. v41 fa+lq Greae aoF I:-- T1121Fk3 W0 3 1.Q 2.49 34 ] 6 t35.s' 43876 4. L-60 ET.IE&d lSCd WS ll�; G90e oetaft rap'Tm Taves xvr4r Wslr:+,eta. iroFml M I 34.0 340 0.00 FL-LW--'R 35' SM OW O4n FV T"Q H.4W w 3.5• L80 EUE &d Mod Fi, 3500 D- nr➢1r:4�'+] 509.3 5093 035 MFfkE 3.5'CYtm T)6' Kppb .W 2812'No.0o PmBe 2W w ac olc; 4oY Yr SMU 8.0 Addy 1. 2.W N004• IMr aeYle�wws T-r am llnCR ALT 4SSiL10.:.C➢ TSF y..II IFkal CI-1 aY Gem .IYI C[YCIIT PVAeIi➢➢ 6,129,0 6,376.1 4401 CTD236•LMI CTDAL3238'LInY, inri+W vao Acthar Sola. Top [9 Bffilt014 1.992 /A'C.Fs• F SIl44Si' a� a LM 43.43 rilOP6TOCK- Ber ak3.5' kdnrat-%Nt*,"al 723131714 uoNoeocrF nasve: este 1, Plarais foa►s a sw� tom: a,ia enol tla TaF{yF91 ni1""I lenpxw cTo]xLbr 4ix Tr►RAarl Cler ply6} Aagr. M1re1 114esb� 0raa > Typ Gvn la ea M tt@ (TYq TTyleeLace vey ew 1RD 1461 inl pR4 pinl] Yy YoOY WFI irc - TTII pa (Fel I4ra Mr Gwn fifa[Ilf'a]n1.0$1Y0 Fnno..cTlcvl: xoaiaa �- . 218".0 2,5062 VrTF KBUG 1 GAB LIFT OLV SK 0 168 1,272.0 3710019 w+msTac YormGnc 2 1,{36.1 3,677.1 ATF 1®LIO 7 CiAB LIFT DV &f 07A 0.0 37PX170 0.]x, Ixyi0.�N'A am4y.4]!t 3 5,664.3 4,5530 WFF KBUO i OAB LIFT CMY BK 0080 wirni9 4 6479:5 5269.3 WTF #Ml.lC 1 GAB LIFT DMY SK 0000 3'IM010 7,414.0 5,600.8 riTF KBUD i GAB LIFT DW BK 0000 0.0 2=0013 6 6,02'30 6,3052 WIF mum 7 L'2 GAS LIFT MY W. 0000 0.0 3'2s7070 11200 cagiest a safety yn m A.WYIar 7,'t9Q011 NOT,. WELL SIDETFWCIMD 8 LATIT3AL.6 ADUED .t t.. Y.ors n•:]uaea 1 a 1- xor4mc >-t4raa � 1. nnrn.0 aaento,m ta.oTs a w anaxa e t11KA Kt. 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Y U U J D OCC t y a o w qZ v Y V) o c c'� N 'V .p NW E o N s wp E A co 15 V W V « N CI Ce W N 2 N O cn a a o a :° 2 a N � y ; *o0 ru d ii N N c0 I 0 I' i� E LU i co co w N N CO CD V V Q a ° a E J tE0H Z to " -- Qt0 O O 0) _ N O J d C r) J a co v E m CL v. 0 co m 2 U U 20 0 0 N N II O10 a '�/��` Co) iZi o 2 w N J Q U I e } G E N Eno < — o o a HIco co o E� I— v co o 5 2 _ G = N a)a) f0 p a))C Z f0 aE Ca o E M SG co N U a) C laDf/ dp I c co Ce Illji Y ° m a) C_ a Q o a I o m O z E v ' GE as co 0 ° z u m O a) p a) CQ N V CO y0 Z O z co O) co p CO co LO LO CO Oc ~ c WCO m o O N II N N co) W t O t N m a a) ce °a c w = ai m 1 E Z a) N y W t0 re G C cc m iii 0 p d Q o p Q o O c C U U U 0 2 'y - .5 a) .a a) )o c E o O a vD oco n Ce Cl E d a p o y LL o 2 aa)) O o m a' E o Q 0. 2 W J 3 3 0 a 0 0 0 a 0 0 214-082 25156 214-083 25157 214-084 25158 Letter of Transmittal Frit214-085 25159 BAKER ( Date: DATA LOGGED December 11 2014 2�t5r�Ot� � M,K.BENDER HUGHES _ _._ ___ _ _______ __ ___ ___ . .._ To: From: State of Alaska AOGCC Baker Hughes 1NTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Paula Lacey paula.lacey@bakerhughes.com Please find enclosed the directional survey data for the following well(s): 3Q-14AL3, 3Q-14AL2, 3Q-14AL1 3Q-14A .),J14,-- Enclosed ,J14 --Enclosed for each well(s): 1 ea. hardcopy prints of final log data reports 1 compact disk containing electronic final log data files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 RECEIVED 900 E. Benson Blvd. DEC 12 2014 Anchorage, Alaska 99508 AOGCC to acknowledge receipt of this data. RECEIVED BY: ôce of Alaska AOGCC I DATE: Guhl, Meredith D (DOA) From: Burke, Jason [Jason.Burke@conocophillips.com] Sent: Wednesday, November 19, 2014 12:37 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA); Eller, J Gary; Gantt, Lamar L; Ohlinger, James J; Phillips, Ron L; Pohler, Cody J; Starck, Kai; Venhaus, Dan E Subject: RE: Data Due, KRU 3Q-14A, 3Q-14A L1, 3Q-14A L2, PTDs 214-082, 214-083, 214-084 Meredith As per our conversation, please hand correct the log from caliper to GR/Res log. In the future we will mark our cement pilot hole logs in this way. Thanks ConochiIlips Jason Burke CTD Engineer - Greater Xuparuk.Area 700 G St#1210 Anchorage, .AX 99501 (0):(907)-265-6097 (M):(907)-231-4568 Jason.Burke@conocophillips.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.dov] Sent: Wednesday, November 19, 2014 12:05 PM To: Burke, Jason Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]Data Due, KRU 3Q-14A, 3Q-14A L1, 3Q-14A L2, PTDs 214-082, 214-083, 214-084 Hello Jason, KRU 3Q-14A and two associated laterals were completed on August 11, 2014.On the 10-407 form submitted, a caliper log was listed as obtained in Box 21. At this time the only data received is the survey data. Data is required to be submitted to the AOGCC within 90 days of well completion (Statute AS 31.05.030), which was November 11. Please submit the caliper logs for KRU 3Q-14A, 3Q-14A L1, and 3Q-14A L2 by December 19, 2014. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 1 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, November 19, 2014 12:05 PM To: 'Burke, Jason' Cc: Bettis, Patricia K(DOA) Subject: Data Due, KRU 3Q-14A, 3Q-14A L1, 3Q-14A L2, PTDs 214-082, 214-083, 214-084 Hello Jason, KRU 3Q-14A and two associated laterals were completed on August 11, 2014. On the 10-407 form submitted, a caliper log was listed as obtained in Box 21.At this time the only data received is the survey data. Data is required to be submitted to the AOGCC within 90 days of well completion (Statute AS 31.05.030), which was November 11. Please submit the caliper logs for KRU 3Q-14A, 3Q-14A L1,and 3Q-14A L2 by December 19, 2014. 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. 1 RECEIVED • STATE OF ALASKA SEP 1 1. 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND AQXJCC la Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b Well Class 20AAC 25 105 20AAC 25.110 Development ❑ ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name 5 Date Comp,Susp, 12 Permit to Drill Number. ConocoPhillips Alaska, Inc _ or Aband: August 11,2014 214-082/ . 3 Address 6 Date Spudded 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 July 24,2014 50-029-21665-01 • 4a Location of Well(Governmental Section) 7 Date TD Reached 14 Well Name and Number Surface: 2289'FNL,2013'FEL,Sec. 17,T13N, RO9E,UM July 29,2014 3Q-14A Top of Productive Horizon: 8. KB(ft above MSL). 60'RKB 15 Field/Pool(s) 2611'FNL,2082'FEL,Sec.20,T13N, RO9E, UM GL(ft above MSL): 17.5'AMSL Kuparuk River Field Total Depth. 1907'FSL, 2149'FWL,Sec.20,T13N,RO9E, UM 9 Plug Back Depth(MD+TVD). 11399'MD/6454'TVD Kuparuk River Oil Pool , 4b Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD): 16.Property Designation Surface: x-516324 y- 6025783 Zone-4 11399'MD/6454'TVD ADL 25512 • TPI: x-516285 y- 6020182 Zone-4 11 SSSV Depth(MD+TVD) 17 Land Use Permit Total Depth: x-515240 y- 6019418 Zone-4 nipple @ 509'MD/509'TVD 2553 18 Directional Survey Yes ❑ No❑ 19 Water Depth,if Offshore 20 Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25 050) N/A (ft MSL) 1558'MD/1546'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071). 22 Re-drill/Lateral Top Window MD/TVD G R-/Qes u,G. "/r/q 8207'MD/6440'ND . 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 115' 37' 115' 24" 1875#Poleset 9.625" 36# J-55 37' 4527' 37' 3747' 12.25" 1250 sx AS III,300 sx Class G 7" 26# J-55 34' 8489' 34' 6645' 8.5" 300 sx Class G,175 sx AS I 2.375" 4.7# L-80 10095' 11399' 6425' 6454' 3" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 8135' 8108'MD/6368'ND 10120'-11399'MD 6424'-6454'TVD ; kr.� 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC 111Was hydraulic fracturing used during completion? Yes❑ No Q iFf DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 8120' 39 bbls 17 ppg 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) September 3,2014 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/5/2014 4 5 hours Test Period--> 30 203 702 104 Bean 7390 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 253 1379 24-Hour Rate-> 149 • 3708 ' 1103 - 21.9 - 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071. NONE RBCMS SEP 2 4 20* Form 10-407 Revised 10/2012 VL /0 3//¢ CONTINUED ON REVERSE -N3I bin/IL, Submit original only ,e //may ,29. GEOLOGIC MARKERS(List all formations and mai Jncountered) 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1558' 1546' needed,and submit detailed test information per 20 AAC 25 071. Top Kuparuk A2 8225' 6455' Top Kuparuk Al 8265' 6475' Top Kuparuk Al 8491' 6471' Top Kuparuk Al 8638' 6463' Top Kuparuk A2 10255' 6424' Top Kuparuk Al 11022' 6419' N/A Formation at total depth: Kuparuk Al 1 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Jason Burke @ 265-6097 Email: Jason.Burke@conocophillips corn Printed Name D.Venhaus Title CTD Engineering Supervisor Signature 7-41:1:101•01Phone 263-4372 Date 7' /1--//4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval) Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 `t],1, F KUP PROD 3Q-14A COn0C0�'11iItipS o Well Attributes 'Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Statusncl(") MD(ftKB) Act Btm(ftKB) G•enorhaps 500292166501 KUPARUK RIVER UNIT PROD ' 100.81 8,440.81 11,399.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-14A,9/10/2014 11 42 45 AM SSSV:NIPPLE 140 12/18/2013 Last WO: 42.51 12/4/1986 Vesical schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK,ADD LATERALS haggea 9/10/2014 1I AL1,AL2,AL3 "-""--HANGER;34.0 -. Casing Strings LI �� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top ThreadI - CONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H-40 Welded '•• ••. 5k.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;37.0-115.0-a a SURFACE 9 5/8 8.765 37.0 4,527.2 3,747.0 36.00 J-55 SMLS Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 34.0 8,488.9 6,471.5 26.00 J-55 BTC NIPPLE;509.3 I..M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread III WINDOW A 7 6.276 8,206.0 8,211.9 6,443.4 GAS LIFT;2.884.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT,4.425.1 0LINERA Liner Details 23/8 1.992 10,094.7 11,399.0/ 6,454.3 4.70 L-80 STL • NominalID- Top(ftKB) Top(TVD)(ftKB) Top Incl I.) Item Des Com (in) 10,094.7 6,424.8 91.55 BILLET 'OH ANCHORED BILLET(Set 08/01/2014) 1.000 10,110.7 6,424.5 90.83 BILLET 01-I ALUMINUM BILLET 1.000 • Tubing Strings Tubing Description String Ma...ID tin) Top(ftKB) Set Depth(ft.Set Depth(WD)(...Wt(Ib/ft) Grade Top Connection SURFACE:37.0.4,5272 a TUBING WO 3 1/2 2.992 34.0 8,135.2 6.387.6 9.30 L-80 EUE 8rd Mod Completion Details GAS LIFT;5,654.2 - Nominal ID ® Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Corn (in) 34.0 34.0 0.00 HANGER 3.5"5M CIW Gen IV Tubing Hanger w/3.5"L-80 EUE 8rd 3.500 GAS LIFT;6,599.5In Mod Pin Down ® 509.3 509.3 0.35 NIPPLE 3.5"Camco'DS'Nipple w%2.812"No-Go Profile 2.812 GAS LIFT;7,414.0 a 8,068.6 6,338.8 42.71 NIPPLE ' 3.5"Camco'W'Nipple w/2.812"Selective Profile 2.812 I 8,108.2 6,367.8 42.94 PACKER 3.5"x 7"Baker'SAB-3'Permanent Packer w/K22 Anchor 3.250 Latch Seal Assy ill 8,125.1 6,380.2 43.03 NIPPLE 3.5"Camco'D'Nipple w/2.750"No-Go Profile 2.750 GAS LIFT;8,023.0 I 8.134.3 6,386.9 43.08 SOS Baker 3.5"Shear Out Sub 2.992 Perforations&Slots NIPPLE:8,068.6 Shot ma Dens I. Top(k613) BtmkKB Top(ND) Btm(ND) (shots/f ( ) (ftKB) (ftKB) Zone Date t) Type Com 10.119.7 11,398.6 6,424.4 6.454.3 A-1,3Q-14 -7/29/2014 SLOTS Slotted Liner PACKER;8,1118.2t°° Mandrel Inserts St r atm C on Top(TVD) Valve Latch Port Size TRO Run LINER AL3;8,119.9-10.040.0 - No Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date APERF;8,119.0-8,122.0 ' _ 1 2,884.0 2,605.2 WTF KBUG 1 GAS LIFT GLV BK- 0.156 1,277.0 8/17/2014 -E 1:30 2 4,425.1 3,677.1 WTF KBUG 1 GAS LIFT GLV BK- 0.188 1,316.0 8/17/2014 2:30 NIPPLE;8,125.1 _ 3 5,654.3 4,553.0 WTF KBUG 1 GAS LIFT OV BK- 0.250 0.0 8/17/2014 1:00 4 6,599.5 5,259.3 WTF KBUG 1 GAS LIFT DMY BK- 0.000 0.0 6/23/2014 SOS;8,134.3 _ 11:30 5 7,414.0 5,859.8 WTF (BUG 1 GAS LIFT 'DMY BK- 0.000 0.0 6/23/2014 1:30 11. 6 8,023.0 6,305.2 WTF MMM 11/2 GAS LIFT DMY RK- 0.000 0.0 6/23/2014 :... 12:00 RPERF;8,204.0-8,248.0, Notes:General&Safety WHIPSTOCK-MONOBORE; 8,206.0 End Date Annotation WINDOW A;8,206.0-8,211.9 7/19/2014 NOTE:WELL SIDETRACKED&LATERALS ADDED PRODUCTION:34D-8.4813.9 h ii 6 SLOTS;8,859.3-10,774.6 LINER AL2;8,550.610,775.0 _ SLOTS;9.842.4-10.064.6 p SLOTS;10,065.9.11,409.6 LINER AL1;9,811.1-11,410.0 ra a. SLOTS;10,119.7-11,398.8 ' 1 LINER A;10,094.7-11,399.0 a ❑ r) ❑ rn a o0 M o- J » (I a V O) II N II ❑ 1 / o Co LO r-Lo N r CO` in II vt ❑ co 1-co co cq ❑ II ��11 M cp o V ❑O N^ a O \ II u) DN❑ V C ❑ C W 0 O 0) a N N aii E O M s•— \\\\11\ ��\ p) MW p__ 0 a) N O V r co— 0 Cl 0 6)R'S Cl ((..,�,��-- F- as co o 1.-- i�J -D.0 .Q- C lJ U OO \ ll C F- C0-- E ^\ CO CU (0_ v co a5 O J O _ O _ N O N E �* ES E Nm E p N co (6((0 CO ,-Q CO Q U of U co 0 r)v7 0 - \ st N N N NN N N N (6 0 co COU) 0) m m M � i 1 iiia o Y ______A o III_ I ..�� M IIIiIt I U 1 ;1 CS 1 I ❑ o I N CD in L N N COO) 0 ❑to ate, N NCO 2E (f) v Cl co W -, -(n -❑a L9 O �� 2,- 2 Y (�o o N�MN ‹Lo0 of (O U) pO 0 v - o ix)/VJ- N 'L N /a d) 43 a 'rZ-14 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 6/21/2014 BRUSHED & FLUSHED TBG TO 8125' RKB, TBG OPEN 2.78". SET 2.75 SV @ SAME. PULLED GLV's @ 2884' , 4425' &5654' RKB, SET DV's @ 2284' &4425' RKB. IN PROGRESS. 6/23/2014 PULLED GLV's @ 6599' & 7414' RKB, PULLED OV @ 8023' RKB, SET DV's @ 5654' , 6599' , 7414'& 8023' RKB. GOOD TBG TEST, ATTEMPT TO PULL SV @ 8125' RKB. IN PROGRESS. 6/24/2014 PULLED 2.75 SV @ 8125' RKB & PREFORMED INJECTIVITY TEST(SEE PUMP REPORT). READY FOR E-LINE. IN PROGRESS. 6/28/2014 PERFORTATED TUBING TAIL FROM 8119' 8122'. FIRED A 3'GUN WITH A 2" OD, 3 SPF PHASED AT 120 DEG. CHARGES WERE HALLIBURTON HMX BIG HOLE. FIRED GUN AT A CCL STOP DEPTH OF 8111.5'WITH A 7' CCL TO TOP SHOT OFFSET. 7/6/2014 RIH WITH BAKER LEFT HANDED MHA, TAG NIPPLE AT 8107' CMTD, PICK UP GET WT BACK, RIH AND TAG AGAIN, PICK UP GOT WT BACK, PICKED UP 5' PAINTED RED FLAG, STARTED MILLING © 1.5 BPM. ©8107' CTMD (8125' RKB)AFTER STALLING MULTIPLE TIMES AND GOING THROUGH SOME FLUID IT WAS DECIDED TO POOH AND CHECK BIT. MADE IT TO 8126' RKB ****RESTART IN THE MORNING**** 7/7/2014 RIH WITH LEFT HANDED BHA 2.80" PARABOLIC DSM. RAN DOWN TO 8112'AND KICKED ON THE PUMP AND MILLED THROUGH THE D NIPPLE HAD SOME MOTOR WORK, MADE IT DOWN TO 8289.5' CTMD POOH AND READY FOR CEMENT IN THE MORNING ****JOB IN PROGRESS**** 7/8/2014 RIH WITH 2.25" BALL DROP JET SWIRL NOZZLE, TAGGED BOTTOM @ 8294.5 RKB, PICK UP 5'AND PAINT FLAG @ 8289.5 RKB, BULLHEADED 1.5 TIMES TUBING VOLUME OF KCL, AND FLUID PACKED THE COIL WITH KCL, COME ONLINE WITH CEMENT, ONCE TWO BBLS WERE OUT OF COIL WE STARTED LAYING IN 1:1 CEMENT, UP TO 7000' SHUT IN TRY TO BUILD SQUEEZE PRESSURE THE HIGHEST WE GOT WAS 587 PSI, PUMP CMT AWAY, GET MORE OUT FOR TOMORROW. ****JOB IN PROGRESS**** 7/9/2014 RIH WITH 2"COIL AND 2.25" BDJSN, TAG @ 7620' CTMD. CALL TOWN TO DISCUSS FURTHER PLAN, POOH, PICK UP MOTOR AND MILL WITH A 2.80" 5 BLADE JUNK MILL, RIH TAG @ 7623', PICK UP GET WT BACK @ 7618'CTMD, PLUS TEN FOOT 7608' CTMD, BRING PUMP ON GET FREE SPIN 2700PSI @ 1.5 BPM. GO IN MILLING AT 10 FPM, WITH MINIMAL MOTOR WORK, TAKE 100' FOOT BITES DOWN TO 8145' RKB, TAKE PUMP TO MINIMUM RATE, DRIFT DOWN TO A TAG @ 8188.8 RKB. TRY INJECTIVITY TEST AT SURFACE, @ .3 BPM WELL PRESSURES UP TO 1650 IN LESS THEN A HALF BBL. ****JOB IN PROGRESS**** 7/10/2014 RIH WITH UNDER REAMER, STOP AND CORRECT TO KNOW DEPTH OF NIPPLE @ 8125', CORRECT TO 8079.48' (ORIGINAL CORRECTION 8106.26 EOP -51' CUT COIL =8055.26 EOP + NEW TOOL STRING= 8079.48' CORRECTED TO END OF TOOLS. RIH TO DRY TAG, TAG @ 8187' CORRECTED DEPTH, PICK UP START UNDER REAMING, SLOW GOING, UNDER REAM DOWN TO 8233.6' CORRECTED DEPTH, DROP .5" BALL TO OPEN UP CIRC SUB, PICK UP AND GET A BOTTOMS UP, DROP PUMP TO MIN. RATE GO IN TAG @ 8233.6. POOH CHASING ANY REMAINING JUNK FROM UNDER REAMING. 1/2 INCH BALL RECOVERED FROM COIL. ****JOB IN PROGRESS**** 7/11/2014 RIH WITH 2.25" BDJSN, ST^P AT FLAG 8055' MAKE CORRECTION O + 6.45= 8061.71', RIH TAG @ 8233.6' PICK i', START PUMPING CMT, LET 2 BBLS T UP AROUND THE COIL AND START LAYING IN 1:1 @ 25 FPM, AT SAFETY, SHUT IN THE CHOKE AND BUILD SQUEEZE PRESSURE TO 1650 PSI, HOLD FOR 15 MIN. LOOKS GOOD, LINE UP TO DROP 5/8 BALL TO START THE CLEAN OUT, ONCE BALL AT NOZZLE BEGIN CLEAN OUT DOWN TO 8110' RKB, RECIPROCATE UP AND DOWN TILL ALL BIO IS OUT OF COIL, CHASE OUT OF HOLE @ 80% SLOWING FOR ALL JEWELRY. AT SURFACE PUT 1450 PSI ON WELL, HELD FOR 10 MIN, HELD GOOD, BLEED DOWN TO 1000 PSI AND SHUT WELL IN, 5/8 BALL RECOVERED ***'WELL IS READY FOR SLICK LINE IN 72 HRS**** 7/15/2014 LOCATED GLM @ 7996' SLM/8023' RKB FOR 27'CORRECTION. TAGGED CMT @ 8096' SLM, EST. 8123' RKB. DRIFTED TBG WITH DUMMY WHIPSTOCK TO 8123' RKB. TESTED TBG 2500 PSI: LOST 275 PSI IN 15 MIN, LOST 500 PSI IN 30 MIN. COMPLETE. 7/16/2014 (PRE-CTD): TREE VALVE PRESSURE TEST POST CEMENT. MASTER VALVE POSITIVE AND NEGATIVE (PASSED), SSV POSITIVE AND NEGATIVE (PASSED), SWAB VALVE POSITIVE AND NEGATIVE (PASSED). Conoco hiIIips Time Log & Summary Welbriew Web Reporting Report Well Name: 30-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/19/2014 12:00:00 AM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/19/2014 24 hr Summary Complete Summer shutdown on 2B Pad 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Complete inner reel iron install on new reel. RDMO 2B pad 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Seperate Rig, mover off of 2B-15, install jeeps, secure BOPE 10:00 10:30 0.50 0 0 MIRU MOVE RURD P PJSM-Peak Trucks on location, hook up to jeeps 10:30 19:00 8.50 0 0 MIRU MOVE MOB P Start 19mile move towards 3Q-pad. 19:00 22:00 3.00 0 0 MIRU MOVE MOB P Arrive on location, remove jeeps, prep cellar, DSO shut/In 3Q-22 producer. 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Spot up rig over 3Q-14, MIRU Note: Midnight RIG ACCEPT 37/20/2014 MIRU, nipple up BOPE, Start BOPE testing 00:00 03:30 3.50 0 0 MIRU WHDBO NUND P Start nipple up, line up riser with bent tree, swap riser with new o-rings, prep for BOPE test,grease manifold and BOPE stack. 03:30 04:15 0.75 0 0 MIRU WHDBO RURD P Fluid pack surface lines, and preform shell test. 04:15 14:00 9.75 0 0 MIRU WHDBO BOPE P Start BOPE Testing,complete test TIW valve Fail/Pass after rebuild and retest.Witness waived by Lou Grimaldi,AOGCC 14:00 15:30 1.50 0 0 MIRU WHDBO CTOP P Prep coil, rig up cable and grapple to stab coil 15:30 16:30 1.00 0 0 MIRU WHDBO PRTS P Pressure test tiger tank line 16:30 18:00 1.50 0 0 MIRU WHDBO MPSP P R/U and pull BPV 18:00 22:00 4.00 0 0 SLOT WELLPF CTOP P Finish Pipe prep and stab coil into injector 22:00 23:00 1.00 0 0 SLOT WELLPF CTOP T Unable to RIH with injector after moving cart-call out Hydra rig and Acadamy rep to trouble shoot. Boot end of e-line 23:00 00:00 1.00 0 0 SLOT WELLPF CTOP P Stab onto well and fill coil 37/21/2014 Complete BOPE test,Witnes waived by Lou Grimaldi,AOGCC, PT tiger tank line, Pull BPV, Fill coil 00:00 02:00 2.00 0 0 SLOT WELLPF BOPE P Complete filling coil, PT inner reel iron and packoffs 02:00 03:36 1.60 0 0 SLOT WELLPF CTOP P Unstab,trim 25'of coil,test wire, all good, prep coil and install connector, Pull test to 37K Page 1 of 18 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:36 04:30 0.90 0 0 SLOT WELLPF CTOP P Head up UQC, Test wire, all good, PT connector to 4K good test 04:30 06:00 1.50 0 0 SLOT WELLPF CTOP P Rack back injector, Stab on PDL and PT to 4200 PSI, install mouseholes 06:00 07:00 1.00 0 0 PROD1 RPEQP1PULD P Pre-Job for PD 07:00 07:30 0.50 0 0 PROD1 RPEQP 1 OWFF P Open up well&bleed down 200PSI SD&monitor 07:30 09:30 2.00 0 62 PROD1 RPEQP1 PULD P Pre-Job make up BHA#1 with D331 mill slick gauge,stab INJH 09:30 11:00 1.50 62 62 PROD1 RPEQP1 TRIP T RIH with milling BHA#1, RIH 100 ft, POOH&inspect coil. Unable to see depth tracking (encoder needed to be switched) 11:00 14:00 3.00 62 100 PROD1 RPEQP1TRIP P Align gooseneck, attempt#2 RIH with milling BHA#1, RIH 100 ft, POOH&inspect coil(PASS), RIH 1000 ft, POOH 200 ft&inspect coil (PASS) 14:00 17:15 3.25 100 7,930 PROD1 RPEQP1DLOG T ****NOTE: Unable to find K1 marker, PUH to get HRZ**** Tie-in 7930'to 8098', GEOs lost (cannot find K1)RIH 150 ft Tagged cement 8117', POOH 7783' Tie-in 7870', POOH to 7700',Tie-in to HRZ correction is+8' 17:15 18:39 1.40 7,930 8,123 PROD1 RPEQP1TRIP P RIH to mill cement, swap to biozan 18:39 00:00 5.35 8,123 8,162 PROD1 RPEQP1MILL P Start milling cement 1.4 BPM 3060 PSI FS, BHP=3500. Multiple stalls around TT and caseing contact —8141 37/22/2014 Fill coil, PT inner reel iron and pack offs. M/U BHA#1,trip in and tie in, Tag TOC @ 8123 mill to 8222', several stalls, diffculty milling cement. POOH for new milling assembly. RBIH milling assembly. 00:00 03:36 3.60 8,162 8,198 PROD1 RPEQP1MILL P Milling cement pilot hole, 1.4 BPM @ 3500 PSI FS 03:36 06:36 3.00 8,198 8,199 PROD1 RPEQP1MILL P Multiple stalls in this area. Hard to get going 06:36 11:36 5.00 8,199 8,216 PROD1 RPEQP1MILL P Milling ahead slowly @ 3 fph. WOB 1.2k, Pick up WT 41k, 1.5 bpm and 3460 psi. Mixed 3%776 lube at nozzle @ 13:37 11:36 14:00 2.40 8,216 8,222 PROD1 RPEQP1MILL P Mixed 3%776 lube at nozzle 13:37, all the way around at 12:13. No noticeable difference in weight transfer or ROP. Mill ahead©3-4 fph with multiple stalls at 8222' CTMD 14:00 16:00 2.00 8,222 8,223 PROD1 RPEQP1 MILL P Lost and erratic tool face causing multiple pick ups. Call made to pull for mill and motor. Orienter check at 8090,Good. 16:00 20:45 4.75 8,222 432 PROD1 RPEQP1TRIP T POOH for new motor and mill assembly. Make adjustments to gooseneck and weight indicator. POOH, on surface, counter showing 432'. Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:15 0.50 432 432 PROD1 RPEQP1 OWFF T No flow check 21:15 22:21 1.10 432 0 PROD1 RPEQP1PULD T PJSM. Inspect coil and LD BHA#1, no evident's of milling failures,take photos of mill, put photos on S drive and send to town. 22:21 23:45 1.40 0 64 PROD1 RPEQP1PULD T PJSM. PU/MU BHA#2 milling assembly with new mill. 23:45 00:00 0.25 64 600 PROD1 RPEQPITRIP T RIH w/milling assembly 07/23/2014 Finish milling cement pilot hole to 8,233', make four back reaming passes,dry drift good. POOH for caliper assembly, LD BHA#3. RIH w/PDS caliper assembly, log pilot hole from 8,230'to 7,700'at 50 fpm. POOH for whipstock assembly. LD BHA#3, PU/MU BHA#4. RIH w/Whipstock assembly, in progress. 00:00 02:45 2.75 600 8,226 PROD1 RPEQPITRIP T Continue in hole with milling assembly,tie-in to HRZ for+16' correction, K1 marker+.5'correction, Tag TOC©8,226'. 02:45 07:45 5.00 8,226 8,233 PROD1 RPEQP1 MILL P Start milling pilothole: 1.4 bpm @ 3,220 PSI, CTW= 13.3K, DHWOB=.7K, ROP=7. Dry drift, back ream as necessary. 07:45 10:03 2.30 8,226 8,233 PROD1 RPEQP1 MILL P Dress off transition area see some motor work @ 8143'. Four down and up passes with reamer, pumps down,dry run looks good. Pump 10 bbl sweep. 10:03 11:27 1.40 8,233 70 PROD1 RPEQP1TRIP P POOH to pick up PDS caliper assembly, Flow check-good. Pre job safety meeting. 11:27 13:45 2.30 70 0 PROD1 RPEQPI PULD P Lay down BHA#2, pilot mill 2.79", pick up nozzle,jet stack, remove nozzle. flow check. 13:45 15:03 1.30 0 70 PROD1 RPEQPI PULD P Pre job safety meeting, rig up PDS memory caliper, stab on well. 15:03 17:33 2.50 70 8,233 PROD1 RPEQPITRIP P RIH W/PDS memory caliper. Questons over tie in at K1, pull up hole to HRZ for tie in, 0 correction, run to 8230',wait 10 minutes for MFC arms to open. 17:33 17:48 0.25 8,233 7,700 PROD1 RPEQPI DLOG P Log with caliper @ 50 fpm from 8,230'to 7,700' 17:48 19:15 1.45 7,700 66 PROD1 RPEQP1 TRIP P POOH with caliper assembly 19:15 21:30 2.25 66 0 PROD1 RPEQP1PULD P On surface, flow check, no flow. LD BHA#3, PDS rep,confirms good caliper data, send data for processing. LD PDS equipment. 21:30 22:00 0.50 0 68 PROD1 RPEQP1PULD P PJSM. PU/MU BHA#4 22:00 00:00 2.00 68 7,956 PROD1 RPEQPITRIP P RIH w/whipstock assemby,while waiting on caliper data. 37/24/2014 Set 3.5" Baker Monobore whipstock @ 8,206'. POOH for window exit assembly. LD BHA#4, PU/MU BHA #5, RIH w/milling assemby, mill window exit as per well plan to 8,215'. Drill rathole to 8,228', back ream window, dry drift clean. POOH for drilling assembly, PUD BHA#5, start PD of BHA#6. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:21 1.35 7,956 8,216 PROD1 RPEQP1 TRIP P Continue in hole with whipstock assembly,tie-in to K1 for+7' correction, PUW=32K, confirm whipstock set depth with town. RIH to set depth TOW @ 8,206', oriented to 0 deg, pressure up to 4,300 psi, release from whipstock,stack 6K down weight. 01:21 02:57 1.60 8,216 66 PROD1 RPEQP1TRIP P POOH for window milling assembly 02:57 03:42 0.75 66 0 PROD1 RPEQP1 PULD P On surface, flow check. LD BHA#4. 03:42 04:45 1.05 0 76 PROD1 WHPST PULD P PJSM. Injector maintenance. PU/MU BHA#5 04:45 07:39 2.90 76 8,207 PROD1 WHPST TRIP P RIH w/window milling assembly.6 degree motor 2.80"string&window mill. String mill go/no go=2.79" Window mill no go=2.80" Tie in at K1, +6.5'correction.,dry tag, pick up wt 35 k 07:39 08:45 1.10 8,197 8,207 PROD1 WHPST WPST P Pumps on,slack off 14.6k, 1.49 bpm, CT 3771 psi, BHP 4379 psi, WH 206 psi, start window milling per procedure. 08:45 14:09 5.40 8,207 8,214 PROD1 WHPST WPST P Time mill per procedure to end of whipstock tray,weight fall off at 8211.9, bottom of window, continue to mill per procedure. 14:09 16:09 2.00 8,214 8,218 PROD1 WHPST WPST P End of theoretical whipstock tray, increase ROP to 2 fph per plan. Bottoms up sample has 10-14% formation solids. 16:09 18:15 2.10 8,218 8,228 PROD1 WHPST WPST P Increase weight on bit per plan. WOB 2.2k, ROP 6.6, CT WT 12.2k, CT 3690 psi, BHP4452 psi, 1.50 bpm,WHP 180 psi, Pick up to reset tool face, up against n stop, Up WT 30 k. RBIH, mill rat hole. 18:15 19:30 1.25 8,228 8,228 PROD1 WHPST REAM P Make three back reaming passes at different tool faces @ 1 fpm,dry drift window,window clean. 19:30 21:30 2.00 8,228 76 PROD1 WHPST TRIP P POOH for drilling BHA 21:30 23:42 2.20 76 0 PROD1 WHPST PULD P PJSM. PUD BHA#5, LD BHA. 23:42 00:00 0.30 0 77 PROD1 DRILL PULD P PJSM. Start PD BHA#6 07/25/2014 PD BHA#6, RIH w/build drilling assembly,tagged up @ 8,228'. Drilled build section as per well plan to called TD @ 8,397'. Pump new mud system, POOH for lateral drilling assembly. PUD BHA#6, PD BHA#7. RIH w/drilling assembly,drill ahead A lateral from 8,397'to 8,815',drilling in progress. 00:00 00:45 0.75 77 77 PROD1 DRILL PULD P Finish PD for BHA#6 00:45 03:00 2.25 77 8,228 PROD1 DRILL TRIP P RIH w/build section drilling assembly:2.3 AKO motor.Tie-in to RA tag for+5'correction, continue in hole,tag up @ 8,228'. Page 4 of 1-81 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:06 3.10 8,228 8,397 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,460 PSI, BHP=3,960 PSI, CTW=12K, DHWOB=1.3K, ROP=40 land build section. 06:06 06:54 0.80 8,397 8,099 PROD1 DRILL CIRC P PUH, and start mud swap to 9.2 Flow Pro 06:54 08:24 1.50 8,099 66 PROD1 DRILL TRIP P New mud out the nozzle, POOH chasing old mud out of hole. 1.4 bpm @ 3903 psi, BHP 3869 psi, CT W=27k off bottom. New mud returns coming back blueish black in color. 08:24 10:24 2.00 66 0 PROD1 DRILL PULD P At surface,tagged up, spaced out, pre job safety meeting, PUD, BHA#6. 10:24 11:42 1.30 0 70 PROD1 DRILL PULD P Pick up A Lat drilling assembly, BHA#7, 11:42 13:30 1.80 0 72 PROD1 DRILL PULD P Crew change/safety meeting, PD BHA#7 13:30 15:00 1.50 72 8,397 PROD1 DRILL TRIP P RIH w/A lat drilling assembly, BH#7, Xtream motor, 0.5 AKO&BH Bi-center 2.7X3 stay sharp bit. 7984'WT Ck 30k Tie in at K1, +5.5'correction. Log RA tag @ 8,213' Set down @ 8,397' 15:00 19:00 4.00 8,397 8,590 PROD1 DRILL DRLG P BOBD: 1.40 BPM @ 3,595 PSI, BHP=4,005 PSI, CTW=10.5K, DHWOB= 1.7K, ROP=80 19:00 19:42 0.70 8,590 8,590 PROD1 DRILL WPRT P Wiper trip, PUW=31K, MAD Pass, RBIH. 19:42 22:54 3.20 8,590 8,790 PROD1 DRILL DRLG P Drill ahead: 1.40 BPM @ 3,610 psi, BHP=4,040 psi, CTW= 11K, DHWOB=2.3K, ROP=50 _ 22:54 23:36 0.70 8,790 8,790 PROD1 DRILL WPRT P Wiper to window, PUW=30K, RBIH. 23:36 00:00 0.40 8,790 8,815 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,590 psi, BHP=3,990 psi, CTW= 11K, DHWOB= 1.3K, ROP=90 07/26/2014 Drill ahead A lateral from 8,815'to 9,950', drilling in progress. 00:00 01:36 1.60 8,815 8,990 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,550 psi, BHP=4,025 psi, CTW= 11K, DHWOB= 1K, ROP=100 01:36 02:39 1.05 8,990 8,990 PROD1 DRILL WPRT P Wiper trip to window, PUW=30K, RBIH @ 02:05 02:39 06:09 3.50 8,990 9,190 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,535 psi, BHP=4,005 psi, CTW= 11K, DHWOB= 1.2K, ROP=60 06:09 06:57 0.80 9,190 8,260 PROD1 DRILL WPRT P Wiper trip#1, PUW=31k, 06:57 07:51 0.90 8,260 9,190 PROD1 DRILL WPRT P RBIH, RIH WT 13.5k 07:51 12:03 4.20 9,190 9,390 PROD1 DRILL DRLG P Drill ahead: 1.40 BPM @ 3,672 psi, BHP=4,054 psi, CTW= 13, DHWOB= 1.2K, ROP=30 12:03 12:45 0.70 9,390 8,403 PROD1 DRILL WPRT P Wiper trip#2, PUW=31 k 12:45 13:33 0.80 8,403 9,390 PROD1 DRILL WPRT P RBIH Page 5 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:33 16:51 3.30 9,390 9,590 PROD1 DRILL DRLG P Drill ahead: 1.41 BPM @ 3,591 psi, BHP=4,027 psi, CTW=11 k, WOB= 1k, ROP=87. Lost MWD TF&NBI trouble shoot, cycle power, all good, drill ahead geostearing. 16:51 18:21 1.50 9,590 9,590 PROD1 DRILL WPRT P Long Wiper, PU WT=31K, RBIH @ 17:40 18:21 21:00 2.65 9,590 9,790 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,650 psi, BHP=4,060 psi, CTW=8.3 k,WOB= 2 k, ROP=90. 21:00 22:06 1.10 9,790 9,790 PROD1 DRILL WPRT P Wiper, PU WT=30K, RBIH @ 21:45 22:06 00:00 1.90 9,790 9,950 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,785 psi, BHP=4,105 psi, CTW=10.8 k, WOB= 1.5k, ROP=95. 07/27/2014 Drill ahead A lateral from 9,950'to 10,679', had several spots wear ankerite was encountered 10,372', 10,472', and 10,675'. Drilling in progress. 00:00 00:27 0.45 9,950 9,990 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,785 psi, BHP=4,105 psi, CTW=10.8 k, WOB= 1.5k, ROP=95. 00:27 01:33 1.10 9,990 9,990 PROD1 DRILL WPRT P Wiper trip, PUW=28K, RBIH @ 01:15 01:33 03:57 2.40 9,990 10,190 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,840 psi, BHP=4,125 psi, CTW=10 k,WOB= 1.7k, ROP= 100. 03:57 04:57 1.00 8,251 10,190 PROD1 DRILL WPRT P Wiper trip, PUW=28K,tie-into RA for+3.5 correction 04:57 05:51 0.90 8,251 10,190 PROD1 DRILL WPRT P RBIH, Mud swap w new mud at the bit @ 10,190' 1793'W 0.8%solids&25k LSRV, on previous system. 05:51 10:15 4.40 10,190 10,375 PROD1 DRILL DRLG P Drill ahead: 1.40 BPM @ 3,600 psi, BHP=4,116 psi, CTW=5.5 k,WOB= 2.7k, ROP=39. Encountered a short drilling break at 10,272' possibly a fault,followed by difficult drilling. Perform BHA wipers as nesc. 10:15 11:03 0.80 10,375 8,823 PROD1 DRILL WPRT P Pulled wiper trip#1 early, PUW=28K, small weight bobble 10,315' 11:03 11:51 0.80 8,823 10,375 PROD1 DRILL WPRT P RBIH, clean hole no WT bobbles. 11:51 18:45 6.90 10,375 10,575 PROD1 DRILL DRLG P BOBD, 1.40 bpm @ 3432 psi, BHP 4130 psi, CTW 0,WOB 1.8, ROP= 4-5. Hard drilling from 10,372 to 10378'. Geo found ankerite in returns. ROP increased rapidly after 10380'to 100. Drill-20'past break, PU to back ream across zone,clean hole, BOBD. Hard spot at 10472' ankerite. 18:45 19:45 1.00 10,575 10,575 PROD1 DRILL WPRT P Wiper to 9,350', PUW=32K, RBIH @ 19:15. 19:45 00:00 4.25 10,575 10,679 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,550 psi, BHP=4,132 psi, CTW=5.7 k,WOB= .8k, ROP=35. Good drilling initially, found ankerite @ 10,675', ROP=3. Page 6 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2014 24 hr Summary Drill ahead A lateral from 10,679'to called TD @ 11,395'. Pump 10 to/hi vis sweeps, chase sweeps to surface. 00:00 02:51 2.85 10,679 10,775 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,550 psi, BHP=4,132 psi, CTW=2.7 k, WOB= .8k, ROP=15. Continue to battle ankerite stringer, broke free @ 10,685'. 02:51 05:12 2.35 10,775 10,775 PROD1 DRILL WPRT P Wiper trip for RA tie-in+6.5' correction, PUW=31.5K, RBIH @ 04:00. 05:12 08:36 3.40 10,775 10,975 PROD1 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,805 psi, BHP=4,185 psi, CTW=7 k,WOB= 1.9k, ROP=85 08:36 09:18 0.70 10,975 9,648 PROD1 DRILL WPRT P Wiper trip#1, PUW=31K, 09:18 10:00 0.70 9,648 10,975 PROD1 DRILL WPRT P RBIH 10:00 14:12 4.20 10,975 11,180 PROD1 DRILL DRLG P BOBD, 1.40 BPM @ 3,737 psi, BHP=4173 psi, CTW=3.3 k,WOB= 2.5k, ROP=29 Turninmg down to ross cut section, dificult drilling, ROPs trending from 30 to10 fph after 11,000' ROP increae @ 11032 from 30 to 90 fph. 14:12 15:24 1.20 11,180 9,770 PROD1 DRILL WPRT P Wiper trip#2, PUW=30.5 K 15:24 16:12 0.80 9,770 11,180 PROD1 DRILL WPRT P RBIH 16:12 20:24 4.20 11,180 11,395 PROD1 DRILL DRLG P BOBD, 1.39 BPM @ 3905 psi, BHP=4203 psi, CTW=7.k, WOB=1.6 k, ROP=90 TD called at 11,395'. 20:24 00:00 3.60 11,395 70 PROD1 DRILL WPRT P PU WT 29k. Pump 10/10 bbl low/ high visc. sweep.Wiper trip to swab at max rate. 37/29/2014 RBIH for corrected TD 11,399', Lay in completion fluid to surface. Monitor well, SITP increase to 25 psi. RBIH to obtain SBHP at window. SITP stabilized at 58 psi while waiting for 12.4 ppg formate from Prudhoe.Weight up completion fluid to 12.6 ppg formate on site, build liner pill and 30 bbl spacer. RBIH 00:00 03:24 3.40 70 11,399 PROD1 DRILL WPRT P RBIH for corrected TD depth, tie-in RA for+4.5' correction,continue in hole,tag bottom,corrected TD @ 11,399'. 03:24 06:54 3.50 11,399 72 PROD1 DRILL DISP P POOH while laying in liner pill/completion fluid, paint EOP flags @ 10,000'and 6,800'. Continue out of hole. 06:54 08:24 1.50 72 72 PROD1 DRILL OWFF P Monitor well for flow.After 30 minutes wellhead 25 psi and climbing, check mud weights in/out 12 PPG. Decide to trip in hole for BHP at window. Page 7 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:24 14:24 6.00 72 8,196 PROD1 DRILL TRIP T RBIH for static BHP,tie-in for+4' correction,start BHP survey, continue to monitored rinsing BHP while waiting on 12.4 PPG Formate from Prudhoe. BHP seems to be stabilzing @ 4073 psi,wellhead 58 psi. 14:24 23:15 8.85 8,196 7,993 PROD1 DRILL COND T Peak on location with 12.4# Formate, offload truck. Decison made to weight up to 12.6#. begin weighting up pits, batch spacer in trip tank. 23:15 00:00 0.75 7,993 9,113 PROD1 DRILL TRIP T RBIH from 7,993' to lay in new 12.6 ppg kill weight beaded liner pill and completion fluids J7/30/2014 RBIH to TD, Lay in new 12.6 ppg completion fluid. MU/TIH and release off"A"lateral liner assembly at TD 11,399'.TOOH, LD BHA#8, PU/TIH with drilling BHA#9. 00:00 02:36 2.60 9,113 11,395 PROD1 DRILL TRIP T Continue RIH to TD, begin pumping spacer. 02:36 06:06 3.50 11,395 72 PROD1 DRILL DISP T 11,395', Spacer out, POOH while laying in 12.6 ppg liner pill/completion fluid, paint EOP flags 10,000'and 6,800'. Continue out of hole. 06:06 06:33 0.45 72 72 PROD1 DRILL OWFF T Monitor well for flow 06:33 09:03 2.50 72 0 PROD1 DRILL PULD P PJSM. LD BHA#7, prep floor liner run,function test BOP. 09:03 11:33 2.50 0 1,280 COMPZ CASING PUTB P PJSM, MU Liner assembly 40 jts slotted, bull nose. 11:33 13:00 1.45 1,280 1,325 COMPZ CASING PULD P PJSM. PU/MU BHA#8, surface test tool. 13:00 16:30 3.50 1,325 11,398 COMPZ CASING RUNL P PJSM. RIH w/Aluminum billet,40jts slotted, bull nose, tie-in for-1' correction,continue in hole,tag bottom 11,398', PUW=35K, bring pump online, release from liner, PUH, PUW=27K. 16:30 19:00 2.50 11,398 44 COMPZ CASING TRIP P POOH for drilling BHA. 19:00 19:30 0.50 44 44 COMPZ CASING OWFF P Monitor well for flow, PJSM to lay down BHA 19:30 20:15 0.75 44 0 COMPZ CASING PULD P LD BHA#8. 20:15 21:39 1.40 0 72 PROD2 STK PULD P PJSM-PU/MU drilling BHA#9, 0.5° AKO motor and Bi-center bit, change out data base, surface test. 21:39 23:15 1.60 72 7,945 PROD2 STK TRIP P TIH with drilling BHA#9. 23:15 23:30 0.25 7,945 7,980 PROD2 STK DLOG P Log K1 marker,+4.5'correction, 29k PUW, 23:30 00:00 0.50 7,980 8,980 PROD2 STK TRIP P Continue TIH with BHA#9 .07/31/2014 Changed well over to 9.2 ppg Flo-Pro. Unable to kick off billet at 10,108.5'with BHA#9, appears to have good motor work, stacking, no aluminum to surface.TOOH, PUD/LD BHA#9, no eveidence of tool failure. MU/PD drilling BHA#10, pumped 2 beaded pills, spud in,wiper, several attempts to kick off failed,TOOH with BHA #10. Page 8 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:39 0.65 8,980 10,109 PROD2 STK TRIP P Continue TIH with BHA#9,dry tag top of billet at 10,108.5', PUW 29k. 00:39 02:24 1.75 10,109 10,109 PROD2 STK DISP P Change over hole to 9.2 ppg Flo-Pro, RBIH 02:24 04:21 1.95 10,109 10,109 PROD2 STK KOST T Time mill off billet 1.4 bpm @ 3590 psi from 10,108.2',WOB 1.2k,400 psi differential, unable make hole or stall motor, PU 26k,clean, RBIH tag up at 10,108.2 with same results, PU,dry tag at 10,109', no aluminum across shaker on first bottoms up, PU 26k,stack out 3.2k, 700 psi differential, unable to stall motor or kick off billet, PU 26k clean, no aluminum across shaker on second bottoms up, confer with town. 04:21 05:03 0.70 10,109 8,250 PROD2 STK TRIP T TOOH to inspect BHA. 05:03 05:15 0.20 8,250 8,220 PROD2 STK DLOG T Log RA marker, +1.5'correction. 05:15 06:48 1.55 8,220 72 PROD2 STK TRIP T TOOH to inspect BHA. 06:48 10:00 3.20 72 0 PROD2 STK PULD T PJSM. PUD BHA#9, Check bit,motor,FVS and BHA. Some balling on bit, nothing conclusive. Call town,decide to change-out BHA. Load PDL. 10:00 11:48 1.80 0 72 PROD2 STK PULD T PJSM. PD BHA#10, surface test tools. 11:48 14:54 3.10 72 10,109 PROD2 STK TRIP T RIH w/drilling assembly,tie-in to K1 for+3.5'correction, continue in hole. Dry tag billet @ 10,108.5'. 14:54 17:54 3.00 10,109 10,109 PROD2 STK KOST T Time mill off billet 1.4 bpm @ 3590 psi from 10,108.2',WOB 1.2k,400 psi differential, appear to have motor work, PU 26k, clean, RBIH tag up at 10,108.2 with same results, PU, no aluminum across shaker on after second bottoms up. confer with town. 17:54 18:24 0.50 10,109 9,310 PROD2 STK TRIP T TOOH to run anchored billet, call back to RBIH and pump beaded pill while attempting to kick off. 18:24 19:15 0.85 9,310 10,107 PROD2 STK TRIP T RBIH with BHA#10, pump 42 bbl hi-vis sweep with 1 ppb Alpine beads. 19:15 21:54 2.65 10,107 10,110 PROD2 STK KOST T Beaded pill at bit,time mill off billet 1 fph, 1.31 bpm at 4025 psi,WOB.6k, CTW 10.5k, apperar to have motor work, no aluminum across shaker on after third bottoms up. confer with town.time milling 1 fph, 1.39 bpm at 3976 psi,WOB 3.2k, CTW 0 at 10,110.2', no aluminum at surface. 21:54 22:09 0.25 10,110 9,600 PROD2 STK WPRT T 10,110', Wiper trip to 9,600', PUW 26k. 22:09 22:21 0.20 9,600 10,110 PROD2 STK WPRT T 9,600',Wiper in hole, RIW 12k Page 9 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:21 23:21 1.00 10,110 10,109 PROD2 STK KOST T 10,110', stack out-2k CWT,WOB 3.9k, appears to have motor work, no stall, no movement. PUW 26k, 1ppb beaded pill at bit,time mill off billet at 10,107.8', 1 fph, 1.31 bpm at 4334 psi,WOB 1.77, CWT 9.2k, attempt 30° L/R OHS no aluminum to surface, PU dry tag at 10,108.5', Conference call with town. 23:21 00:00 0.65 10,109 8,618 PROD2 STK TRIP T 10,110', TOOH to run anchored billet, PUW 26k. 08/01/2014 TOOH, PUD BHA#10, MU/PD BHA#11, Set Anchored Billet at 10,108', TOOH, PUD BHA#11, Prep for and begin Bi-weekly BOP test,witnessed by John Crisp,AOGCC. 00:00 01:51 1.85 8,618 72 PROD2 STK TRIP T 8,618', Continue TOOH with BHA #10 01:51 03:30 1.65 72 0 PROD2 STK PULD T PJSM-PUD/LD BHA#10, Bit clean, no indication of BHA problems. 03:30 04:00 0.50 0 0 PROD2 STK PULD T PJSM-PU/MU Ported Bull Nose,4' pup jt.,Achored Billlet to BHA#11, Load into PDL 04:00 05:00 1.00 0 77 PROD2 STK PULD T PD BHA#11 and anchored billet assembly,surface test tool. 05:00 09:54 4.90 77 10,108 PROD2 STK TRIP T TIH with Anchored Billet BHA#11, tie in to K1 for+4'correction, close EDC. Continue in hole,tag bottom @ 10,108', PUW=29.5K, set back down, bring pump online, release from billet @ 4,300 psi, TOB @ 10,090', PUW=29K. 09:54 11:54 2.00 10,108 76 PROD2 STK TRIP T POOH with BHA#11 11:54 14:15 2.35 76 0 PROD2 STK PULD T PJSM. PUD BHA#11, LD BHA. Decide to perform Bi-weekly BOP test. Called State got the OK. 14:15 18:30 4.25 0 0 PROD2 WHDBO RURD T Install nozzle, load coil with water, prep for BOP test,valve crew seviced tree, hydraulic leak at HCR valve, replace HCR. Perform shell test. 18:30 00:00 5.50 0 0 PROD2 WHDBO BOPE T Perform Bi-weekly BOPE test.Test witnessed by John Crisp,AOGCC. 08/02/2014 Complete Bi-weekly BOP test,witnessed by John Crisp,AOGCC. MU/PD BHA#12, Kick off anchored billet at 10,090'. Drill ahead AL1 lateral to 10,646'. 00:00 01:00 1.00 0 0 PROD2 WHDBO BOPE T Complete Bi-weekly BOPE test.Test witnessed by John Crisp,AOGCC. 01:00 02:30 1.50 0 0 PROD2 WHDBO RURD T PJSM-RD test equipment, load coil with drilling mud,service rig choke, valve check list 02:30 03:00 0.50 0 0 PROD2 STK PULD T PJSM-MU drilling BHA#12, .7° AKO motor and bi-center bit, 03:00 04:00 1.00 0 72 PROD2 STK PULD T PJSM-PD BHA#12, make up to coil,surface test. 04:00 06:51 2.85 72 10,090 PROD2 STK TRIP T TIH with BHA#12, tie in to K1 for +6.5'correction,close EDC. Continue in hole,tag top of billet at 10,090'. Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:51 09:21 2.50 10,090 10,090 PROD2 STK KOST P Start milling billet: 1.50 bpm @ 3,550 psi, BHP=4,245 psi, CTW=11 K, DHWOB=.5K, several stalls, 09:21 09:45 0.40 10,090 10,090 PROD2 STK REAM P Back ream above billet 100'to 9,985'. RBIH. 09:45 12:00 2.25 10,090 10,094 PROD2 STK KOST P Start time milling billet as per well plan at 1,2,5 FPH: 1.50 bpm @ 3,650 psi, BHP=4,245 psi, CTW=11 K, DHWOB=.5K. 12:00 13:00 1.00 10,094 10,130 PROD2 STK KOST P Start drilling at 10, 20 and 45 fph to 10,130'. PUH to drift billet, PUW=29K. RBIH,drift looks good. 13:00 15:00 2.00 10,130 10,290 PROD2 DRILL DRLG P DOBD: 1.51 BPM @ 3850 psi, BHP=4275 psi, CTW=9K, WOB=1.7K, ROP=90 15:00 16:51 1.85 10,290 10,290 PROD2 DRILL WPRT P Wiper trip to window, PUW=28K, RBIH @ 16:00. 16:51 19:51 3.00 10,290 10,490 PROD2 DRILL DRLG P DOBD: 1.52 BPM @ 37250 psi, BHP=4325 psi, CTW=8.5K, WOB=1.8K, ROP=130 19:51 20:21 0.50 10,490 9,640 PROD2 DRILL WPRT P 10,490',Wiper up hole, PUW 29k 20:21 20:45 0.40 9,640 10,490 PROD2 DRILL WPRT P Wiper in hole, RIW 10k 20:45 00:00 3.25 10,490 10,646 PROD2 DRILL DRLG P 10,490', OBD 1.50 bpm @ 3880 psi, BHP 4253 psi, CTW 6.1k,WOB 1.6k, ROP 100, IA 1337, OA 604, J8/03/2014 Drill ahead AU lateral from 10,646'to 11,191'. 00:00 00:42 0.70 10,646 10,690 PROD2 DRILL DRLG P 10,646', OBD 1.50 bpm @ 3986 psi, BHP 4343 psi, CTW 5.4k,WOB 1.6k, ROP 80, IA 1337, OA 604 00:42 01:51 1.15 10,690 10,690 PROD2 DRILL WPRT P 10,690', Wiper trip to window, PUW 29k. 01:51 02:00 0.15 10,690 10,690 PROD2 DRILL DLOG P Log RA marker, +6.5'correction. 02:00 03:06 1.10 10,690 10,690 PROD2 DRILL WPRT P 8,250', Wiper in hole 03:06 06:39 3.55 10,690 10,890 PROD2 DRILL DRLG P 10,690', OBD 1.50 bpm @ 3906 psi, BHP 4273 psi,WH 180, CTW 6.5k, WOB 1.4k, ROP 80, IA 1337, OA 604, one 250' BHA wiper with 5X5 sweep. 06:39 09:00 2.35 10,890 10,890 PROD2 DRILL WPRT P Wiper trip, PUW=29K, RBIH @ 07:40 09:00 13:39 4.65 10,890 11,072 PROD2 DRILL DRLG P Drill ahead: 1.42 BPM @ 3725 psi, BHP=4325,CTW=4.5K,WOB=.5K, ROP=60, had to make several short wiper trips, hit couple ankerite stringers, pull tie-in wiper early. 13:39 16:18 2.65 11,072 11,072 PROD2 DRILL WPRT P Wiper trip for tie-in and hole cleaning, PUW=29K,tie-in for+3'correction, RBIH @ 15:10. 16:18 00:00 7.70 11,072 11,191 PROD2 DRILL DRLG P Drill ahead: 1.44 BPM @ 3885 psi, BHP=4297, CTW=-3.5K, WOB=2.35K, ROP=10, 38/04/2014 Drill ahead AL1 lateral from 11,191'to 11,410'. Wiper to swab, RBIH for corrected TD at 11,410'.TOOH laying in liner running pill/completion fluid to surface. Monitor well. LD BHA#12 Page 11 of 18 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:24 1.40 11,191 11,192 PROD2 DRILL DRLG P Drill ahead: 1.44 bpm @ 3765 psi, BHP 4316, CTW-4.5k,WOB 1.2k, several attempts to get started, make several short wiper trips, pull wiper early. pump 5x5 sweep 01:24 02:36 1.20 11,192 9,990 PROD2 DRILL WPRT P 11,192',Wiper up hole, PUW 27k 02:36 03:18 0.70 9,990 11,192 PROD2 DRILL WPRT P 9,990', Wiper in hole, RIW 10.5k. 03:18 09:48 6.50 11,192 11,362 PROD2 DRILL DRLG P 11,192', OBD 1.50 bpm @ 3902 psi, BHP 4312, CTW-5.5k,WOB 1.7k, ankerite stringers. 09:48 10:51 1.05 11,362 11,362 PROD2 DRILL WPRT P Wiper trip to billet, PUW=28K, RBIH. 10:51 11:51 1.00 11,362 11,400 PROD2 DRILL DRLG P Drill ahead: 1.46 bpm @ 4080 psi, BHP 4340, CTW 2 k,WOB 2 k, ROP=40. Decide from town to extend TD 100'. 11:51 13:09 1.30 11,400 11,400 PROD2 DRILL WPRT P Pump sweeps, perform wiper trip, while waiting on anti-collision survey. 13:09 13:24 0.25 11,400 11,410 PROD2 DRILL DRLG P Drill ahead: 1.46 bpm @ 4080 psi, BHP 4340, CTW 3.5 k,WOB 1.8 k, ROP=40. 13:24 16:48 3.40 11,410 66 PROD2 DRILL WPRT P Pump to/hi vis sweeps, PUW=29K, chase sweeps to swab. 16:48 18:06 1.30 66 7,940 PROD2 DRILL WPRT P RBIH for corrected TD 18:06 18:18 0.20 7,940 7,980 PROD2 DRILL DLOG P Log K1 marker, +3.5'correction. 18:18 19:45 1.45 7,980 11,410 PROD2 DRILL WPRT P Continue in hole,tag corrected TD at 11,410', PUW 29k. 19:45 22:36 2.85 11,410 66 PROD2 DRILL DISP P TOOH while laying in 12.6 ppg beaded liner pill/completion fluid, paint EOP flags @ 9,900'and 6,700'. Continue out of hole. 22:36 23:06 0.50 66 0 PROD2 DRILL OWFF P Monitor well for flow. PJSM-Laying down BHA. 23:06 00:00 0.90 0 0 PROD2 DRILL PULD P PJSM. LD BHA#12, 08/05/2014 Run AL1 lower liner to 11,410', upper liner to 10,065'set on Anchored billet 150° ROHS.TIH with Drilling BHA #15,Tag Top of Billet at 9,810'. 00:00 00:45 0.75 0 0 COMPZ CASING PUTB P Service injector, inspect top drive, prep floor for liner run. 00:45 02:15 1.50 0 1,345 COMPZ CASING PUTB P PJSM-MU AU lower liner assembly, Shorty,42 jts slotted, bull nose, BOP drill. 02:15 03:00 0.75 1,345 1,389 COMPZ CASING PULD P PJSM-MU BHA#13, MU to coil, surface test. 03:00 05:54 2.90 1,389 11,400 COMPZ CASING RUNL P PJSM. RIH w/Shorty deployment sleeve,42 jts slotted, bull nose,tie-in for+1.5'correction, continue in hole, tag bottom 11,400', PUW 38k, bring pump online, release from liner, PUH, PUW 27k. 05:54 08:33 2.65 11,400 16 COMPZ CASING TRIP P TOOH for upper liner assembly 08:33 08:45 0.20 16 16 COMPZ CASING TRIP P At surface. 08:45 09:27 0.70 16 16 COMPZ CASING OWFF P PJSM for LD BHA#13.Watch well for flow. Page 12 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:27 10:21 0.90 16 0 COMPZ CASING PULD P LD BHA#13. 10:21 11:15 0.90 0 0 COMPZ CASING PUTB P PJSM for running liner. Start MU upper section of liner assembly. 11:15 12:15 1.00 0 315 COMPZ CASING PULD P PJSM for PU BHA#14. PU BHA #14. 12:15 14:51 2.60 315 8,200 COMPZ CASING RUNL P TIH pumping at minimum rate with OH anchored billet, 2 solid pups,7 joints of slotted liner and a ported bull nose. 14:51 15:06 0.25 8,200 8,205 COMPZ CASING DLOG P @ 8,200' Start logging down and up pass. Tie in correction of+3.5' 15:06 15:54 0.80 8,205 10,065 COMPZ CASING RUNL P Continue TIH with upper liner assembly. IA= 1,283 psi OA= 511 psi CT WT= 14.42k 15:54 16:06 0.20 10,065 10,065 COMPZ CASING RUNL P Tag @ 10,065'. Pick up wieght and change toolface.Tag again. Release from anchored billet @ 9,811'. Toolface at 150 right of high side. PUW=31K, adjust counter to BHA 9,811'. 16:06 18:12 2.10 10,065 61 COMPZ CASING TRIP P TOOH for drilling BHA 18:12 18:42 0.50 61 61 COMPZ CASING OWFF P Monitor well for flow. PJSM-laying down BHA 18:42 19:30 0.80 61 0 COMPZ CASING PULD P LD BHA#14. 19:30 21:24 1.90 0 72 PROD3 STK PULD P PJSM-PU/MU drilling BHA#15,0.6° AKO motor and Bi-center bit, calibrate micro motion, inspect injector, change out packoffs, make up to coil, surface test. 21:24 23:06 1.70 72 7,940 PROD3 STK TRIP P TIH with BHA#15 23:06 23:18 0.20 7,940 7,980 PROD3 STK DLOG P Log K1 marker, +4'correction. 23:18 00:00 0.70 7,980 9,810 PROD3 STK TRIP P Contiue TIH with BHA#15,Tag top of billet at 9,810', pick up hole slowly PUW 29k. 38/06/2014 Displace well to drilling fluid. Kick off billet at 9,810', Drilled AL2 lateral to planned TD 10,775'. 00:00 02:15 2.25 9,810 9,810 PROD3 STK DISP P Displace hole to 9.2 ppg drilling fluid. 02:15 04:42 2.45 9,810 9,812 PROD3 STK KOST P 9,810', Several stalls before begining time milling billet as per well plan at 1,2,5 fph, 1.48 bpm @ 3,760 psi, BHP 4,195 psi, CTW 11.2k, DHWOB .4k.aluminum across shaker. 04:42 05:30 0.80 9,812 9,835 PROD3 STK KOST P Start drilling at 10,20 and 45 fph to 9,835'. PUH to drift billet, PUW 29k, RBIH,drift looks good. 05:30 08:06 2.60 9,835 10,035 PROD3 DRILL DRLG P 9,835', OBD 1.48 bpm @ 3916 psi, BHP 4228 psi, CWT 10.2k,WOB 1.7k, ROP 70 08:06 08:51 0.75 10,035 8,250 PROD3 DRILL WPRT P @10,035'Wiper up hole. 08:51 09:39 0.80 8,250 10,035 PROD3 DRILL WPRT P @ 8,250'WIH. 09:39 13:24 3.75 10,035 10,235 PROD3 DRILL DRLG P BOBD. 1.47 bpm CP=3,672 psi WHP=435 psi BHP=4,277 psi IA= 1,323 psi OA=644 psi Page 13 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:24 14:03 0.65 10,235 9,000 PROD3 DRILL WPRT P © 10,235.0 WUH 14:03 14:39 0.60 9,000 10,235 PROD3 DRILL WPRT P @ 9,000' WIH 14:39 16:36 1.95 10,235 10,435 PROD3 DRILL DRLG P BOBD. 1.47 bpm CP=3,919 psi WHP=390 psi BHP=3,928 psi IA = 1,339 psi OA=668 psi 16:36 17:42 1.10 10,435 8,232 PROD3 DRILL WPRT P @ 10,435' WUH and make RA tie-in correction of+5' 17:42 18:42 1.00 8,232 10,435 PROD3 DRILL WPRT P @ 8,232' WIH .30 bpm WHP= 451 psi CP=3217 psi IA= 1,339 psi OA=681 psi Coil WT= 12.8k 18:42 21:00 2.30 10,435 10,635 PROD3 DRILL DRLG P 10,435', BOBD 1.47 bpm @ 4020 psi, BHP 4290 psi, CWT 7.8k,WOB 1.7k, ROP 70 21:00 21:39 0.65 10,635 9,445 PROD3 DRILL WPRT P 10,635', Wiper up hole, PUW 30k. 21:39 22:12 0.55 9,445 10,635 PROD3 DRILL WPRT P 9,445', Wiper up hole, RIW 11.7k, IA 1346, OA 703 _ 22:12 00:00 1.80 10,635 10,775 PROD3 DRILL DRLG P 10,635', BOBD 1.47 bpm @ 4046 psi, BHP 4240 psi, CWT 6.5k,WOB 1.9k, ROP 80,TD AL2 lateral at 10,775'. 08/07/2014 Chase Sweep to swab. RBIH for corrected TD at 10,775',TOOH laying in liner running pill/completion fluid to surface. Monitor well. LD BHA#15. Run AL2 lower liner to 10,775', upper liner to 8,858'set on Anchored billet 30° ROHS.TOOH. 00:00 02:30 2.50 10,775 72 PROD3 DRILL WPRT P 10,775',Wiper to swab chasing 10x10 sweep, PUW 30k 02:30 03:57 1.45 72 7,950 PROD3 DRILL WPRT P Bump up, adjust counter to BHA,TIH for tie in, corrected TD. 03:57 04:06 0.15 7,950 7,980 PROD3 DRILL DLOG P Log K1 marker, +4'correction. 04:06 05:18 1.20 7,980 10,775 PROD3 DRILL WPRT P Continue in hole,tag corrected TD at 10,775', PUW 32k. 05:18 08:36 3.30 10,775 89 PROD3 DRILL DISP P TOOH while laying in 12.6 ppg beaded liner pill/completion fluid, paint EOP flags @ 8,700'and 6,100'. Continue out of hole. 08:36 08:51 0.25 89 89 PROD3 DRILL OWFF P At surface. Monitor well for flow. 08:51 09:06 0.25 89 89 PROD3 DRILL SFTY P PJSM for laying down BHA#15 09:06 10:15 1.15 89 0 PROD3 DRILL PULD P Lay down BHA#15. Inspect flat spot about 8'above coil connector.Wall thickness is.145 Confer with town engineer and will rehead after liner run. 10:15 10:39 0.40 0 0 COMPZ CASING SFTY P PJSM for running AL2 lower liner assembly. 10:39 12:57 2.30 0 1,964 COMPZ CASING PUTB P M/U AL2 lower liner assembly. 12:57 13:12 0.25 1,964 1,964 COMPZ CASING SFTY P PJSM for M/U BHA assembly. 13:12 14:03 0.85 1,964 1,964 COMPZ CASING PULD P M/U BHA assembly. Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T comment 14:03 16:21 2.30 1,964 10,775 COMPZ CASING RUNL P RIH with AL2 slotted liner to TD. Bull nose,60 joints of slotted liner,and a shorty deployment sleeve. Made tie-in correction of-.36' TD @ 10, 775.0, release from liner and TOOH. 16:21 18:06 1.75 10,775 44 COMPZ CASING TRIP P TOOH for Upper Liner Assembly. PUW=31k 18:06 18:36 0.50 44 44 COMPZ CASING OWFF P Monitor well for flow. PJSM-laying down BHA. 18:36 19:21 0.75 44 0 COMPZ CASING PULD P LD BHA#16 19:21 20:15 0.90 0 308 COMPZ CASING PUTB P PJSM-MU Upper AL2 liner assembly, Ported bull nose,9 jts slotted, 2x6'pup jts,Anchored billet. 20:15 21:09 0.90 308 369 COMPZ CASING PULD P PJSM-MU BHA#17, make up to coil, surface test. 21:09 23:24 2.25 369 8,260 COMPZ CASING RUNL P TIH with Upper AL2 liner assembly on BHA#17. 23:24 23:39 0.25 8,260 8,280 COMPZ CASING DLOG P Log K1 marker, +4'correction, PUW 34k, pumps down, close EDC. 23:39 00:00 0.35 8,290 8,858 COMPZ CASING RUNL P Continue TIH with BHA#17, tag top of lower liner at 8,858', PUW 34k, set back down, PU to neutral, bring pump online, release from billet @ 4,400 psi, TOB at 8,550', PUW 32.5k, change counter to BHA depth 08/08/2014 TOOH. LD BHA#17.Trim 20'of pipe, head up, MU/TIH with BHA#18.Tag Top of Billet at 8,550', Displace well to drilling fluid. Kick off billet at 8,550', Drilled AL3 lateral to 9,030'. 00:00 01:36 1.60 8,858 61 COMPZ CASING TRIP P TOOH with BHA#17. 01:36 02:09 0.55 61 61 COMPZ CASING OWFF P Monitor well for flow. PJSM-Laying down BHA 02:09 03:24 1.25 61 0 COMPZ CASING PULD P LD BHA#17. clean floors,prep to cut pipe. 03:24 05:54 2.50 0 0 PROD4 DRILL CTOP P PJSM-Trim 20'of 2"pipe due to.140 flat spot 8'above connector, head up, pull test 40k, P/T 4k. 05:54 06:21 0.45 0 0 PROD4 STK SFTY P PJSM for M/U BHA#18. 06:21 07:54 1.55 0 72 PROD4 STK PULD P M/U Drilling BHA. 07:54 09:54 2.00 72 8,550 PROD4 STK TRIP P TIH with Drilling BHA to anchored billet at 8,550' 09:54 10:00 0.10 8,550 8,550 PROD4 STK TRIP P Tag anchored billet @ 8,550'. 10:00 11:06 1.10 8,550 8,550 PROD4 STK DISP P PUH and reciprocate coil while pumping to displace wellbore with drilling fluids 11:06 14:06 3.00 8,550 8,575 PROD4 STK KOST P RIH and begin milling on billet.2.2 to .6 fph WOB=0.69 to 1.7 1.46 bpm WHP=330 psi CP=3,822 psi IA= 1,313 OA=599 psi Coil WT=9.41 k 2 stalls encountered. 14:06 14:12 0.10 8,575 8,537 PROD4 STK KOST P PUH to and"dry drift"through billet. No issues with drift;went pretty smooth Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:12 17:18 3.10 8,537 8,775 PROD4 DRILL DRLG P BOBD ahead in AL3 lateral. 1.5 bpm WHP=334 psi CP=4,008 psi IA = 1,325 psi OA=646 PSI 17:18 18:03 0.75 8,775 8,775 PROD4 DRILL WPRT P @ 8,775' wiper up hole to 8,250'. PUW=27.9 k, RBIH 18:03 22:09 4.10 8,775 8,975 PROD4 DRILL DRLG P 8,775', BOBD 1.47 bpm @ 3985 psi, BHP 4132 psi, CWT 9.5k,WOB 1.4k, ROP 65 22:09 22:36 0.45 8,975 8,250 PROD4 DRILL WPRT P 8,975', Wiper Up hole, PUW 31k. 22:36 23:03 0.45 8,250 8,975 PROD4 DRILL WPRT P Wiper in hole RIW 12.4k, IA 1332, OA 700. 23:03 00:00 0.95 8,975 9,030 PROD4 DRILL DRLG P 8,975', BOBD 1.47 bpm @ 4004 psi, BHP 4175 psi, CWT 10.6k,WOB 1.5k, ROP 60 08/09/2014 Drill ahead AL3 lateral from 9,030'to planned TD 10,040', Chase sweeps to swab. 00:00 02:15 2.25 9,030 9,175 PROD4 DRILL DRLG P 9,030', BOBD 1.47 bpm @ 4004 psi, BHP 4190 psi, CWT 10.6k,WOB 1.5k, ROP 65 02:15 02:48 0.55 9,175 8,230 PROD4 DRILL WPRT P 9,175', Wiper up hole for tie in, PUW 29k. 02:48 02:57 0.15 8,230 8,250 PROD4 DRILL DLOG P Log RA marker, +2'correction. 02:57 03:30 0.55 8,250 9,175 PROD4 DRILL WPRT P 8220', Wiper trip in hole, RIW 14k. IA 1335, OA 716 03:30 07:09 3.65 9,175 9,375 PROD4 DRILL DRLG P 9,175', BOBD 1.44 bpm @ 3908 psi, BHP 4183 psi, CWT 9.0k,WOB 1.8k, ROP 65 Note: Perform mud swap, new 9.2 ppg FloPro at bit at 9,246', Old system- 1,662'drilled with.8%drill solids. 07:09 07:39 0.50 9,375 8,600 PROD4 DRILL WPRT P @ 9,375' Wiper up hole. PUW= 27k 07:39 08:03 0.40 8,600 9,375 PROD4 DRILL WPRT P @ 8,600' Wiper in hole. RIW= 11.7 k 08:03 10:48 2.75 9,375 9,575 PROD4 DRILL DRLG P BOBD 1.5 bpm CP=4,007 psi WHP=369 psi IA=1339 psi OA =724 psi Coil WT= 10.6k 10:48 11:21 0.55 9,575 8,609 PROD4 DRILL WPRT P @ 9,575' Wiper up hole PUW= 27.5 k 11:21 11:48 0.45 8,609 9,575 PROD4 DRILL WPRT P @ 8,609' Wiper in hole. RIW 10.8 k 11:48 14:54 3.10 9,575 9,775 PROD4 DRILL DRLG P BOBD 1.43 bpm CP=3,871 psi WHP=341 psi IA= 1,342 psi OA =740 psi 14:54 15:45 0.85 9,775 8,220 PROD4 DRILL WPRT P @ 9,775' Wiper up hole. PUW= 27.9 k 15:45 15:57 0.20 8,220 8,250 PROD4 DRILL DLOG P Log RA marker and make correction of+3'. 15:57 16:39 0.70 8,250 9,775 PROD4 DRILL WPRT P @ 8,250.0' Wiper in hole RIW= 10.3 k 16:39 19:33 2.90 9,775 9,975 PROD4 DRILL DRLG P BOBD 1.42 bpm CP=3,918 psi WHP=318 psi IA= 1,345 psi OA =752 psi Coil Wt=8.9 k 19:33 20:09 0.60 9,975 9,100 PROD4 DRILL WPRT P 9,975', Wiper up hole, PUW 28k Page 16 of 18 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:09 20:48 0.65 9,100 9,975 PROD4 DRILL WPRT P 9,100', Wiper in hole, RIW 12k, IA _ 1348, OA 768. 20:48 21:42 0.90 9,975 10,040 PROD4 DRILL DRLG P 9,975', BOBD 1.42 bpm @ 3934 psi, BHP 4245 psi, CWT 8.2k,WOB 1.5k, ROP 65,TD AL3 lateral at 10,040'. 21:42 00:00 2.30 10,040 2,650 PROD4 DRILL WPRT P 10,775',Wiper to swab chasing 10x10 sweep, PUW 27k 38/10/2014 Tag corrected TD at 10,040', Lay in 12.6 ppg completion fluid from TD to surface, LD BHA#18, MU AL3 liner assembly on BHA#19, Realease off liner at 10,040',Top of AL3 liner at 8,120', Displece well to seawater, Freeze protect with diesel from 2,500', PUD BHA#19. 00:00 00:39 0.65 2,650 132 PROD4 DRILL WPRT P Continue wiper to swab chasing sweep. 00:39 01:09 0.50 132 132 PROD4 DRILL SVRG P PJSM-LOTO of reel, inspect hub bolts and saddle clamp bolts for tightness, cleaned countered 01:09 03:00 1.85 72 7,950 PROD4 DRILL WPRT P Bump up, adjust counter to BHA,TIH for tie in, corrected TD. 03:00 03:12 0.20 7,950 7,980 PROD4 DRILL DLOG P Log K1 marker, +4'correction. 03:12 04:39 1.45 7,980 10,040 PROD4 DRILL WPRT P Continue in hole,tag corrected TD at 10,040', PUW 30k. 04:39 07:48 3.15 10,040 79 PROD4 DRILL DISP P TOOH, Lay in 12.6 ppg beaded liner pill/completion fluid, paint EOP flags @ 8,000'and 6,100'. Continue out of hole. 07:48 08:18 0.50 79 79 PROD4 DRILL OWFF P At surface. Monitor well for flow. 08:18 08:36 0.30 79 79 PROD4 DRILL SFTY P PJSM for L/D of BHA#18. 08:36 09:36 1.00 79 0 PROD4 DRILL PULD P L/D BHA#18. 09:36 10:06 0.50 0 0 PROD4 DRILL BOPE P BOP function test completed. 10:06 10:21 0.25 0 0 COMPZ CASING SFTY P PJSM for P/U AL3 Liner 10:21 12:15 1.90 0 0 COMPZ CASING PUTB P Start picking up AL3 Liner 12:15 12:27 0.20 0 0 COMPZ CASING SFTY P BOPE Safety Drill 12:27 12:42 0.25 0 0 COMPZ CASING SFTY P PJSM for M/U BHA#19 12:42 13:42 1.00 1,926 1,964 COMPZ CASING PULD P M/U BHA#19 13:42 15:12 1.50 1,964 8,066 COMPZ CASING RUNL P TIH with AL3 Lateral Liner. .30 bpm CP=813 psi WHP= 10 psi IA= 1,275 OA=568 psi RIW= 10.86 k 15:12 15:15 0.05 8,066 8,066 COMPZ CASING DLOG P At EOP flag. Make correction of-2'. PUW=30.3k 15:15 15:54 0.65 8,066 10,040 COMPZ CASING RUNL P Continue TIH to TD @ 10,040'. RIW = 10.3 k IA= 1,277 psi OA= 574 psi WHP=5 psi Hung up above end of pipe at 9,988.0 PUH and went RIH again no issues on the second attempt.Tag botton at 10, 038.6' PUH and RIH again.Tag at 10,040.0' 15:54 16:06 0.20 10,040 10,040 COMPZ CASING RUNL P Bring pumps on and release from liner, PUH several feet PUW= 27.8 k, 8,120.0'is top of liner. Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:06 18:24 2.30 8,107 8,107 DEMOB WELLPF DISP P Start pumping viscosified pill(15 bbls)and then switch to seawater to displace wellbore.TOOH pumping seawater to 2,500'. 18:24 19:42 1.30 2,510 2,510 DEMOB WELLPF FRZP P PJSM with LRS, RU and load coil with 28 bbl diesel, RDMO LRS. 19:42 20:18 0.60 2,510 44 DEMOB WELLPF FRZP P TOOH laying in diesel freeze protect. 20:18 23:00 2.70 44 0 DEMOB WELLPF PULD P PJSM-PUD amnd LD BHA#19. 23:00 00:00 1.00 0 0 DEMOB WHDBO MPSP P PJSM-RU and pressure test FMC equipment. 08/11/2014 Set BPV. Nipple down BOP, Secure rig, RDMO CDR2 00:00 01:00 1.00 0 0 DEMOB WHDBO MPSP P Set BPV, RD and off load FMC equipment. 01:00 08:00 7.00 0 0 DEMOB WHDBO NUND P Circulate,flush stack&lines. Continue with rig down. Nipple down BOPE. Load tree with methanol and secure. Rig Released at 8:00 Page 18 of 18 3Q-14 WELL WORK SUMMARY • DATE SUMMARY POST RIG WELL WORK 8/17/2014 GAUGED TBG TO 2.60"TO LINER TOP @ 8120' RKB. MEASURED BHP © 8120' RKB: 4009 PSI. SET CATCHER ON LINER TOP. PULLED DV, SET OV© 5654' RKB. PULLED DVs @ 4425' &2884' RKB, SET GLVs. ATTEMPTED PULL CATCHER; UNABLE TO PASS GLM @ 8023' RKB. IN PROGRESS. 8/18/2014 LIB INDICATED FILL© 7986'SLM. BAILED FRAC SAND FROM 7986'-7900'SLM. IN PROGRESS. 8/19/2014 BAIL FRAC SAND FROM 7988'-7992' SLM. IN PROGRESS. 8/20/2014 BAIL FILL FROM 7993' SLM — 8006'SLM. IN PROGRESS. 8/21/2014 BAIL FILL FROM 8008'-8029' SLM; PULLED CATCHER @ 8120' RKB. JOB COMPLETE. IIII le MN z W; ` SzN C. M I ci a (0 O 0. (I) co 0 w W W Q i— >, •- O. �, — .E .- +J . 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Letter of Transmittal ///11 BAKER Date: AugustDATA LOGGED 19' 2014 /2.0/20141/2.0/20141HUGHES M.K.BENDER To: From: Meredith Guhl Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): -14A 2v-1-D Z 2-441 .41 • 3Q-14AL1 2\44-0 • og RECEIVED 3Q-14AL2 2_‘.4-k•01514 2.4109 3Q-14AL3 OSS 2'11 tO AUG 20 2014 AOGCC (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager G�✓��,�, � y��N; Yosha.Ragbirsingh@BakerHughes.com _ ` v Q r-- 0 -i" c: 0 ii 2 am z `W; gi 00 6 Q 1- 4pl p2 Iib' N C) c as 0 .. 0_ co 0 0 — W D a 1— ,, 0 Z 2 •� c - �- �' s .- to U t.0 It � _- ? mo O 0 ix M to ■ ,- N C 0 ,C .Y N4-) L_ N E C C a 3 Q N W c4 V 0 aa � o c 0 Q 0 PI 03 13 V )o a D 03kill °3 00 8m O O r r CO - 0 O) r P co N i F d A sr O co z O 6 I '0 v _ -0CO Cal E w d y 11 w N. Q I N. LL 0. U 1 c 0 0 v o d o N m 0 O O 1 N N Nco Ito > y a) J A7 ft COc 0) O d J J CD to Q• O av m O v Cr- 0 0 0 coo • N- d 9 N N 7 a E d O OTO O U) omm m v U O vO@ © QR o0 NO w v O NM V '7 d d w + m 'C c7 07 H 2 W d 'o. 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Lipp 2 2 a ,-- W p p N 2 7 O O rOp V ac a a O 77 p v 2 uCO Cv v v O COv ° aDv aD O Lo a V N N COM uN O N aV O O N M N M O 0 O U) U) CCA u) u) N U) U) UI Ui O O O O 0i CO d G r 8 nO O O 8 `,L":2 O N N N M A M = O t6 V p C T $. O O .-- e- .- r r .- o a- a V oo - dww O 0 a iq 0 coN. 4__:„.,,,,,, Il/ 1 HE STATE A.i 2.:, ,..., ,.., ,C ,:, ..;; -- -telj 4_r 2_..'_-1,s 1_-. J �_ _ .L t ` -- — -- 333 West Seventh Avenue "'-:,- Go RNOIZ SEAN PAR\1=1 i, Anchorage. Alaska 99501-3572 M 'Q r D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3Q-14A ConocoPhillips Alaska, Inc. Permit No: 214-082 Surface Location: 2289' FNL, 2013' FEL, Sec. 17, T13N, R09E, UM Bottomhole Location: 1937' FSL, 2143' FWL, Sec. 20, T13N, R09E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development 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, :Vef Cathy 7Foerster Chair DATED this Z3 day of June 2014. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 8 2014 PERMIT TO DRILL 20 AAC 25.005 AO CC 1a.Type of Work: 1 b Proposed Well Class: Development-Oil ❑• Service-Winj ❑ Single Zone ❑✓ , 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone El Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑., Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal El Shale Gas ❑ 2 Operator Name: 5. Bond U Blanket s U Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180. 3Q-14A r 3.Address. 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD. 11400' • TVD. 6377'I Kuparuk River Field 4a Location of Well(Governmental Section): 7 Property Designation(Lease Number) Surface'2289'FNL,2013'FEL,Sec. 17,T13N, RO9E, UM ADL 25512 • Kuparuk Oil Pool . Top of Productive Horizon 8.Land Use Permit. 13 Approximate Spud Date: 2310'FSL,2605'FEL, Sec.20,T13N, RO9E, UM 2553 7/1/2014 Total Depth: 9.Acres in Property: 14 Distance to 1937'FSL,2143'FWL, Sec.20,T13N, RO9E, UM • 2560 ` Nearest Property: 11600 4b.Location of Well(State Base Plane Coordinates-NAD 27). 10 KB Elevation above MSL 60 feet 15 Distance to Nearest Well Open Surface:x- 516324 y- 6025783 Zone- 4 • GL Elevation above MSL: 22 feet to Same Pool' 3N-09,1100' 16.Deviated wells. Kickoff depth: - 8215 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: •100° deg Downhole•4378 psig • Surface:3728 psig - 18 Casing Prosram Specifications Top - Setting Depth -Bottom Cement Quantity,c.f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3' 2.375" 4.7# L-80 ST-L 650 10750' 6369' 11400' 6377' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft): Junk(measured) 8506 6657 none 8401' 6580' 8356', 8395' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 1875#Poleset 115' 115' Surface 4490' 4527' 1250 sx AS III, 300 sx CI G 4527' 3747' Intermediate Production 8455' 8489' 300 sx Class G, 175 sx AS I 8489' 6645' Perforation Depth MD(ft): Perforation Depth TVD(ft): 8204'-8248', 8258'-8302' 6438'-6470', 6477'-6509' 20.Attachments: Property Plal❑ BOP Sketch❑ Drilling Prograrr ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21 Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jason Burke @ 265-6097 Email Jason.Burke@conocophillips.com Printed Name -, D. Venhaus Title CTD Engineering Supervisor Signature C.�=--;"e_...-7:,;;7,..--;;;;0.--,p1..1--- Phone:265-6120 Date 4 17-- 0-1 Commission Use Only Permit to Drill API Number. Permit Approval See cover letter Number: p�` y 1:531, 50-p Q9 _ 09,16(05 -O( -00 I Date: ts1_�3 -.),42)‘..--1 for other requirements i Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbedm hane,gas hydrates,or gas contained in shales' Other: SOP ft-5 t to 4 2C DPS , Samples req'd: Yes No [► Mud log req'd: Yes❑ No 121 H2S measures: Yes No r❑ Directional svy req'd: Yes u No Spacing exception req'd: Yes " Yes ❑ No u Inclination-only svy req'd: Yes❑ No P o c t) I 1 I A Rc BY THE 2 f,/ Approved by: COI I N R" \Yt o mEiMiDsroN Date -�-7--fel Form 10-401 (Re ised 10/2012) This permit is valid for 24 months fromthe ate of pr9va(20 AAC 25.005(g)) # aX?(t. VLF 77e//4 ' ` ,rV RECEIVED ConocoPhillips JUN 18 2014 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 9, 2014 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a six lateral well out of the Kuparuk well 3Q-14 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in July 2014. The CTD objective will be to drill six laterals(3Q-14A, 3Q-14AL1, 3Q-14AL2, 3Q-14AL3, 3Q-14AL4 &3Q-14AL5), targeting the A sand intervals./A cement plug must be placed in the 7"casing of well 3Q-14 to facilitate a casing exit for these laterals, which will likewise effectively plug off the existing perforations. There is insufficient room to plug the perfs in accordance with 20 AAC 25.112 (c), so ConocoPhillips requests a variance from the plugging requirements of 20 AAC 25.112(c)to facilitate the casing exit of the 3Q-14 horizontal laterals. The proposed plugging procedure meets the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents: — 10-403 Sundry application to plug A-sand perfs in 3Q-14 — Permit to Drill Application Form 10-401 for 3Q-14A, 3Q-14AL1, 3Q-14AL2, 3Q-14AL3, 3Q-14AL4& 3Q- 14AL5 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, 41110IP Jason Burke Coiled Tubing Drilling Engineer 907-231-4568 ' r Kuparuk CTD Laterals 11 3Q-14A, AL1, AL2, AL3, AL4 & AL5 `onofta° " 2 Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) Error! Bookmark not defined. (Requirements of 20 AAC 25.402) Error!Bookmark not defined. 17. Attachments 8 Attachment 1: Directional Plans for 2T-32A&2T-32AL1 8 Attachment 2: Current Well Schematic for 2T-32 8 Attachment 3: Proposed Well Schematic for 2T-32A&2T-32AL1 8 Page 1 of 8 Q R I G I A L 6/11/2014 • PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3Q-14A, AL1, AL2, AL3, AL4 & AL5. All laterals will be classified as"Development- Oil'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 3Q-14A, AL1, AL2,AL3,AL4&AL5. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4200 psi. Using the maximum formation pressure in the area of 4378 psi in the 3N-11, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3728 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 3Q-14 in February 2014 indicated a reservoir pressure of 2462 psi or 7.3 ppg equivalent mud weight. The maximum down hole pressure in the 3Q-14 pattern is at 3N-11 with 4378 psi. It is expected that reservoir pressure as high as 3N-11 may be encountered while drilling the 3Q-14 laterals because we will be drilling towards that fault block. Using the 3N-11 pressure as the maximum possible,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3728 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection is currently being performed on the 3Q-13, so the drilling fluid will need to be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 3Q-14 laterals will be high differentials between fault blocks because we are drilling from a low pressure block into a higher pressure block. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 8 ! MAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 &AL5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3Q-14A 10,750' 11,400' 6,369' 6,377' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL1 10,150' 11,400' 6,391' 6,377' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL2 10,080' 10,600' 6,391' 6,413' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL3 9,305' 10,580' 6,360' 6,360' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL4 8,525' 9,900' 6,409' 6,373' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL5 8,120' 9,150' 6,301' 6,319' 2%", 4.7#, L-80, ST-L slotted liner; Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.50 H-40 Welded 37' 115' 0' 115' 1640 630 Surface 9-5/8" 36 J-55 SMLS 37' 4527' 0' 3747' 3520 2020 Casing 7" 26 J-55 BTC 34' 8489' 0' 6644' 4980 4330 Tubing 3 '/2" 9.2 L-80 EUE-MOD 34' 8135' 0' 6387' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based Flo-Pro mud (9.2 ppg) - Drilling operations: Chloride-based Flo-Pro mud (9.2 ppg)./This mud weight will hydrostatically overbalance the reservoir pressure; we will maintain these conditions using MPD practices described below. - Completion operations: 3Q-14 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-198 bbl)of at least 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 8 ORIGINAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of the minimum of 12.0 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and expected draw down reservoir pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3Q-14 Window(8,215' MD, 6386' TVD Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (7.3 ppg) 2447 psi X31 2447 psi Mud Hydrostatic(9.2 ppg) 3084 psi 3084 psi Annular friction (i.e. ECD, 0.090 psi/ft) 739 psi 0 psi Mud + ECD Combined 3828 psi 3084 psi (no choke pressure) (overbalanced (overbalanced —1376 psi) —637 psi) T ,t BHP at Window(12.0 ppg) 4022 psi 4022 psi Choke Pressure Required to Maintain Target BHP 199 psi 938 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A -Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Page 4 of 8 oRIGINAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Summary of Operations Background Well 3Q-14 is a Kuparuk A-sand development well equipped with 3'/2"tubing and 7"production casing. Six laterals from well 3Q-14 will be drilled to the Southwest side of parent well 3Q-14 to access reserves in an adjacent fault block. These laterals will target the Al,A2&A3 sands. The D-Nipple located at 8125' MD will have the ID milled out to a 2.80"to allow the drilling assemblies access through the tubing tall. The tubing tail will also be perforated prior to cementing to allow cement between the 3-1/2"tubing tail and 7"casing. Prior to drilling,the existing A-sand perfs in 3Q-14 will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requested a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in this manner in the Sundry application(Approved 314-146) After plugging off the existing A-sand perfs with cement,pilot hole drilled,a mechanical whipstock will be placed in the 7"casing at the planned kickoff point. The 3Q-14A sidetrack will exit through the 7"casing at 8215' MD and all subsequent laterals will be drilled off of this sidetrack. The laterals will be completed with 2-%" slotted liner. The final liner will be run with the top located inside the 3'/2"tubing at 8120' MD. Pre-CTD Work 1. RU slickline—Dummy off GLM adn obtain a SBHP 2. RU Pump—Perform injectivity test 3. RU E-Liner—Perforate tubing tail at 8119'—8121' MD 4. RU coil—Mill out D-nipple at 8125' MD then pump cement and squeeze A-perfs. 5. RU slick-line-Tag top of cement and pressure test. 6. Prep site for Nabors CDR2-AC,including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3Q-14A Sidetrack(Al & A2 sand- Southwest) a. Drill 2.80"high-side pilot hole through cement to 8265' MD b. RU Slickline—caliper pilot hole c. Drift pilot hole with whip-stock dummy d. Set whip-stock at 8215' MD with high-side orientation e. Mill 2.80"window at 8215' MD f. Drill 2.74"x 3.0"bi-center lateral to TD of 11400' MD g. Run 2%"slotted liner with an aluminum billet from TD up to 10750' MD 3. 3Q-14AL1 Lateral(A2&A3 sand-Southwest) a. Kick off of the aluminum billet at 10750' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 11400' MD c. Run 2%"slotted liner from TD up to 10150' MD Page 5 of 8 6/11/2014 ORIGINAL PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 &AL5 4. 3Q-14AL2 Lateral(Al sand-Southwest) a. Kick off of the aluminum billet at 10150' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 10600' MD c. Run 23/8"slotted liner from TD up to 10080' MD 5. 3Q-14AL3 Lateral(A3 sand- Southwest) a. Kick off of the aluminum billet at 10080' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 10580' MD c. Run 2%"slotted liner from TD up to 9305' MD 6. 3Q-14AL4 Lateral(Al & A2 sand-Southwest) a. Kick off of the aluminum billet at 9305' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 9900' MD c. Run 2%"slotted liner from TD up to 8525' MD 7. 3Q-14AL5 Lateral(Al & A2 sand- Southwest) a. Kick off of the aluminum billet at 8525' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 9150' MD c. Run 2%"slotted liner into the tubing tail at 8120' MD 8. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV. 3. Turn over to production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. Page 6 of 86/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 &AL5 — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 3Q-14 CTD laterals will be displaced to an overbalancing fluid (12.0 ppg NaBr) prior to running liner. See the"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 3Q-14A 11600' 3Q-14AL1 11600' 3Q-14AL2 11600' 3Q-14AL3 11600' 3Q-14AL4 11600' 3Q-14AL5 11600' — Distance to Nearest Well within Pool (heel measured to offset well) Page 7 of 8 6/11/2014 ORIGINAL • PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Lateral Name Distance Well 3Q-14A 1100' 3N-09 3Q-14AL1 1100' 3N-09 3Q-14AL2 1100' 3N-09 3Q-14AL3 1100' 3N-09 3Q-14AL4 1100' 3N-09 3Q-14AL5 1100' 3N-09 16. Attachments Attachment 1: Directional Plans for 3Q-14A, AL1, AL2, AL3, AL4 &AL5 Attachment 2: Current Well Schematic for 3Q-14 Attachment 3: Proposed Well Schematic for 3Q-14A, AL1, AL2, AL3, AL4 &AL5 Page 8 of 8 6/11/2014 ORG ! N1LU R 11 Q 11 Q- 0Qn 1 �1Ln 2 O 1t It O 1..- 1.0 In �.1 11, d,O o 11 Ii �o it "I a'-U /�� I1 11 11 •ct 7 0 1I 11 113 �- 11 r 11 It coOm a Q= II 1I M♦-m 11 it I. 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U).— II" P`t U �„ I■Ie V M O o 0 _co EL 2 Lo 1 @ Q `9 Q a) 0 N V)-00p (c Oo O L oo `t op (Na) o) �1 a) N t0 V dW F-W O '9 d a i V Q -) 0 N N� coIt Q W co op j-- V 6)V ORIGINAL KUP PROD 3Q-14 ,--- ConocoP1.iHips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(MB) Act Btm(fIKB) ' r,,,rr, „g,r„ 500292166500 KUPARUK RIVER UNIT PROD 47.28 4,000.00 8,506.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-14,2/11/20141 08:47 PM SSSV:NIPPLE 150 12/24/2012 Last WO: 2/1/1998 42.51 12/4/1986 Verbal schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date ........_..__............. Last Tag:SLM 8,274.0 2/7/2014 Rev Reason:TAG hipshkf 2/11/2014 x HANGER.34 I 9 9 0 I'V Ili Castn Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MOB) Set Depth(ND)... Wt/Len(I..:Grade Top Thread I I CONDUCTOR 16 15.062 37.0 115.0 115.0 62.50 H-40 Welded memeeetneemeo Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;37.0-115.0-, > SURFACE 95/8 8.765 37.0 4,527.2 3,747.0 36.00 J-55 SMLS Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WI/Len(I..:Grade Top Thread PRODUCTION 7 6276 34.0 8,488.9 6,644.6 26.00 J-55 BTC NIPPLE;509,3 ■ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibltt) Grade Top Connection GAS UFT;2,884.0 <-. TUBING WO 31/2 2.992 34.01 8,135.2 6,387.5 9.30 L-80 EUE 8rd Mod 1 Completion Details _ Nominal ID GAS LIFT;4,425.1 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.0 34.0 0.03 HANGER 3.5"5M CIW Gen IV Tubing Hanger w/3.5"L-80 EUE 8rd 3.500 Mod Pin Down • 509.3 509.3 0.35 NIPPLE 3.5"Camco'DS'Nipple w/2.812"No-Go Profile 2.812 • 8,068.6 6,338.8 42.71 NIPPLE 3.5"Camco'W Nipple WI 2.812"Selective Profile 2.812 SURFACE;37.0-4,527.2 a- 8,108.2 6,367.8 42.94 PACKER 3.5"x T'Baker'SAB-3'Permanent Packer w/K22 Anchor 3250 Latch Seal Assy GAS LIFT;5,654.2 8,125.1 6,380.2 43.03 NIPPLE 3.5"Camco'D'Nipple w/2.750"No-Go Profile 2.750 8,1343 6,386.9 43.08 SOS Baker 3.5"Shear Out Sub 2.992 GAS LIFT;6.599.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) Fl Des Com Run Date ID(in) GAS LIFT;7,414.08,356.0 6,548.0 43.43 FISH 1"X 2"Piece of Tree Saver Left in Hole 10/14/1991 0.000 < 8.395.0 6,576.4 43.43 FISH 1 1/2"OV w/RK Latch Empty Pocket;Dropped to 2/8/1998 0.000 Rathole GAS LIFT;8,023.0 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB( (ftKB) (ftKB) Zone Date t) Type Corn NIPPLE;8,068.6 s 8,204.0 8,248.0 6,437.7 6,469.6 A-3,A-2,3Q- 4/11/1991 6.0 RPERF 2 1/8"Dyna Strip;0 deg 14 ph - 8211.0 8,212.0 6,442.7 6,443.5 A-4,30-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 deg.phasing PACKER;8,1082 a _ 8214.0 8,215.0 6,444.9 6,445.6 A-3,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 deg.phasing NIPPLE;8,125.1 VI 8234.0 8,235.0 6,459.4 6,460.2 A-2,30-14 3/2/1987 1.0 (PERF 2 1/8"HJ II EnerJet;0 deg.phasing 8237.0 8,238.0 6,461.6 6,462.3 A-2,3Q-14 3/2/1987 1.0'IPERF 2 1/8"HJ II EnerJet;0 SOS;8.134.3 11 deg.phasing 8258.0 8,302.0 6,476.9 6,508.8 A-1,3Q-14 4/11/1991 6.0 RPERF 21/8"Dyna Strip;0 deg ph 8259.0 8,261.0 6,477.6 6,479.0 A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 deg.phasing _ 8264.0 8,265.0 6,481.2 6,482.0 A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 IPERF;8,211.012.0 deg.phasing 8,2 8266.0 8,267.0 6,482.7 6,483.4 A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 _ deg.phasing IPERF;8,214.0-8215.0 8269.0 8,270.0 6,484.9 6,485.6 A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 RPERF;8,204.0-8,248.0 - deg.phasing IPERF;8,234.0-8,235.0 8274.0 8,276.0 6,488.5 6,489.9 A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 _ deg.phasing 8278.0 8,279.0 6,491.4 6,492.1"A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 lc IPERF;8,237.0-8.238.0- r ,237.0-8,238.0 r.-_-_• deg.phasing 8286.0 8,288.0 6,497.2 6,498.7'A-1,3Q-14 3/2/1987 1.0 IPERF 2 1/8"HJ II EnerJet;0 deg.phasing Mandrel Inserts St IPERF;8,259.0-8.261.0-ira as C on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date m IPERF;8.264.0.8.265.0 1 2,884.0 2,605.2 WTF KBUG 1 GAS LIFT GLV BK 0.156' 1296.0 10/4/2013 2 4,425.1 3,677.1 WTF KBUG 1 GAS LIFT GLV BK 0.156 1,295.0 10/4/2013 IPERF;8.266.08.267.0 = 3 5,654.2 4,553.0 WTF KBUG 1 GAS LIFT GLV BK 0.156 1,292.0 10/4/2013 c 4 6,599.5 5,259.3 WTF KBUG 1 GAS LIFT GLV 'BK 0.188 1,324.0 10/5/2013 5 7,414.0 5,859.8 WTF KBUG 1 GAS LIFT 'GLV BK 0.188 1,316.0 10/5/2013 ..-- IPERF;8,269.0-8,270.0 6 8.023.0 6,3052 WTF MMM 11/2 GAS LIFT OV IRK 0.188 0.0 10/3/2013 C Notes:General&Safety IPERF;8,274.0-8,276.0 r- End Date Annotation 1/30/2004 NOTE:WAIVERED WELL: IA x OA COMMUNICATION - 3/26/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 tc IPERF;8,278.08,279.0 RPERF;8,258D-8,302.0- IPERF;8,286.08,288.0 FISH;8,358.0 e FISH;8,385.0 PRODUCTION;34.08,488.9 I. (''''' i N A, 1 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-14 3Q-14A Plan: 3Q-14A_wp04 Standard Planning Report 14 May, 2014 r BAKER HUGHES ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 30-14 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-14A Design: 30-14A_wp04 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 Site Kuparuk 3Q Pad Site Position: Northing: 6,025,873.15ft Latitude: 70°28'54.757 N From: Map Easting: 515,959.89ft Longitude: 149°52'10.513 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.12° Well 3Q-14 Well Position +N/-S 0.00 ft Northing: 6,025,783.47 ft Latitude: 70°28'53.867 N +EI-W 0.00 ft Easting: 516,323.80 ft Longitude: 149°51'59.814 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3Q-14A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 8/1/2014 15.07 80.01 57,400 Design 30-14A_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,200.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (') 0.00 0.00 0.00 189.88 5/14/2014 2:21:41PM Page 2 COMPASS 2003.16 Build 69 lir ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-14 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-14A Design: 30-14A_wp04 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,200.00 43.43 160.00 6,374.75 -4,386.00 1,204.44 0.00 0.00 0.00 0.00 8,215.00 43.43 159.95 6,385.64 -4,395.69 1,207.97 0.23 0.00 -0.33 -90.02 8,236.00 46.37 159.95 6,400.52 -4,409.61 1,213.05 14.00 14.00 0.00 0.00 8,355.18 100.00 159.95 6,433.75 -4,512.91 1,250.75 45.00 45.00 0.00 0.00 8,465.18 97.23 209.98 6,416.17 -4,617.65 1,241.47 45.00 -2.52 45.48 89.00 8,535.18 95.94 214.74 6,408.14 -4,676.37 1,204.26 7.00 -1.84 6.80 105.00 8,835.18 96.22 235.86 6,376.00 -4,885.01 993.46 7.00 0.10 7.04 88.10 9,035.18 91.77 249.16 6,362.00 -4,976.81 816.89 7.00 -2.23 6.65 108.00 9,235.18 90.03 235.27 6,358.85 -5,069.79 640.41 7.00 -0.87 -6.95 263.00 9,385.18 87.50 225.08 6,362.10 -5,165.70 525.40 7.00 -1.68 -6.80 256.00 9,510.18 79.52 228.68 6,376.22 -5,250.53 434.85 7.00 -6.39 2.89 156.00 9,660.18 89.86 230.50 6,390.09 -5,347.20 321.27 7.00 6.90 1.21 10.00 9,860.18 89.33 244.49 6,391.51 -5,454.41 153.03 7.00 -0.26 7.00 92.20 10,010.18 90.16 234.02 6,392.17 -5,530.99 24.29 7.00 0.55 -6.98 274.50 10,160.18 92.69 223.83 6,388.43 -5,629.37 -88.59 7.00 1.68 -6.80 284.00 10,460.18 92.51 244.85 6,374.67 -5,803.12 -330.71 7.00 -0.06 7.01 90.00 10,660.18 90.03 231.06 6,370.22 -5,908.96 -499.76 7.00 -1.24 -6.89 260.00 10,810.18 91.84 241.41 6,367.77 -5,992.20 -624.27 7.00 1.21 6.90 80.00 11,010.18 89.86 227.55 6,364.79 -6,108.11 -786.62 7.00 -0.99 -6.93 262.00 11,210.18 87.69 241.38 6,369.08 -6,224.04 -948.92 7.00 -1.08 6.92 99.00 11,400.00 87.76 228.08 6,376.65 -6,333.31 -1,103.43 7.00 0.03 -7.01 270.00 5/14/2014 2:21.41PM Page 3 COMPASS 2003.16 Build 69 rr ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-14 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-14A Design: 3Q-14A_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) 0100ft) (0) (ft) (ft) 8,200.00 43.43 160.00 6,374.75 -4,386.00 1,204.44 4,114.18 0.00 0.00 6,021,400.56 517,537.74 TIP 8,215.00 43.43 159.95 6,385.64 -4,395.69 1,207.97 4,123.12 0.23 -90.02 6,021,390.88 517,541.29 KOP 8,236.00 46.37 159.95 6,400.52 -4,409.61 1,213.05 4,135.96 14.00 0.00 6,021,376.97 517,546.40 End 14 dls,Start 45 dls 8,300.00 75.17 159.95 6,431.44 -4,461.53 1,232.00 4,183.85 45.00 0.00 6,021,325.10 517,565.46 8,355.18 100.00 159.95 6,433.75 -4,512.91 1,250.75 4,231.26 45.00 0.00 6,021,273.76 517,584.32 4 8,400.00 99.73 180.42 6,425.99 -4,556.18 1,258.23 4,272.60 45.00 89.00 6,021,230.52 517,591.90 8,465.18 97.23 209.98 6,416.17 -4,617.65 1,241.47 4,336.04 45.00 92.54 6,021,169.01 517,575.27 End 45 dls,Start 7 dls 8,500.00 96.59 212.35 6,411.98 -4,647.23 1,223.58 4,368.24 7.00 105.00 6,021,139.40 517,557.45 8,535.18 95.94 214.74 6,408.14 -4,676.37 1,204.26 4,400.27 7.00 105.29 6,021,110.22 517,538.20 6 8,600.00 96.07 219.30 6,401.35 -4,727.83 1,165.46 4,457.63 7.00 88.10 6,021,058.68 517,499.51 8,700.00 96.20 226.34 6,390.66 -4,800.71 1,097.92 4,541.02 7.00 88.58 6,020,985.65 517,432.14 8,800.00 96.23 233.38 6,379.82 -4,864.76 1,021.97 4,617.15 7.00 89.33 6,020,921.45 517,356.34 8,835.18 96.22 235.86 6,376.00 -4,885.01 993.46 4,641.99 7.00 90.09 6,020,901.14 517,327.88 7 8,900.00 94.80 240.19 6,369.77 -4,919.17 938.75 4,685.04 7.00 108.00 6,020,866.86 517,273.24 9,000.00 92.57 246.83 6,363.33 -4,963.64 849.48 4,744.17 7.00 108.42 6,020,822.20 517,184.09 9,035.18 91.77 249.16 6,362.00 -4,976.81 816.89 4,762.74 7.00 108.84 6,020,808.96 517,151.53 8 9,100.00 91.21 244.66 6,360.32 -5,002.22 757.30 4,798.00 7.00 -97.00 6,020,783.43 517,092.00 9,200.00 90.34 237.71 6,358.96 -5,050.38 669.74 4,860.47 7.00 -97.12 6,020,735.08 517,004.55 9,235.18 90.03 235.27 6,358.85 -5,069.79 640.41 4,884.64 7.00 -97.21 6,020,715.60 516,975.27 9 9,300.00 88.93 230.87 6,359.44 -5,108.73 588.61 4,931.88 7.00 -104.00 6,020,676.55 516,923.56 9,385.18 87.50 225.08 6,362.10 -5,165.70 525.40 4,998.86 7.00 -103.96 6,020,619.45 516,860.48 10 9,400.00 86.55 225.50 6,362.87 -5,176.12 514.88 5,010.92 7.00 156.00 6,020,609.01 516,849.98 9,500.00 80.17 228.39 6,374.43 -5,243.90 442.36 5,090.15 7.00 155.98 6,020,541.08 516,777.62 9,510.18 79.52 228.68 6,376.22 -5,250.53 434.85 5,097.97 7.00 155.64 6,020,534.43 516,770.13 11 9,600.00 85.71 229.78 6,387.77 -5,308.67 367.42 5,166.82 7.00 10.00 6,020,476.15 516,702.83 9,660.18 89.86 230.50 6,390.09 -5,347.20 321.27 5,212.70 7.00 9.86 6,020,437.52 516,656.77 12 9,700.00 89.75 233.28 6,390.22 -5,371.77 289.94 5,242.29 7.00 92.20 6,020,412.88 516,625.50 9,800.00 89.49 240.28 6,390.89 -5,426.52 206.34 5,310.58 7.00 92.19 6,020,357.95 516,542.02 9,860.18 89.33 244.49 6,391.51 -5,454.41 153.03 5,347.20 7.00 92.14 6,020,329.95 516,488.78 13 9,900.00 89.55 241.71 6,391.89 -5,472.43 117.52 5,371.04 7.00 -85.50 6,020,311.86 516,453.32 10,000.00 90.11 234.73 6,392.19 -5,525.06 32.57 5,437.47 7.00 -85.47 6,020,259.05 516,368.49- 10,010.18 90.16 234.02 6,392.17 -5,530.99 24.29 5,444.73 7.00 -85.45 6,020,253.10 516,360.23 14 10,100.00 91.68 227.92 6,390.72 -5,587.51 -45.44 5,512.39 7.00 -76.00 6,020,196.43 516,290.63 10,160.18 92.69 223.83 6,388.43 -5,629.37 -88.59 5,561.04 7.00 -76.10 6,020,154.48 516,247.57 15 10,200.00 92.68 226.62 6,386.56 -5,657.39 -116.83 5,593.48 7.00 90.00 6,020,126.40 516,219.40 10,300.00 92.65 233.62 6,381.90 -5,721.40 -193.43 5,669.69 7.00 90.13 6,020,062.23 516,142.94 10,400.00 92.57 240.63 6,377.34 -5,775.59 -277.28 5,737.47 7.00 90.46 6,020,007.86 516,059.22 5/14/2014 2:21:41PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-14 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-14A Design: 3Q-14A_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 10,460.18 92.51 244.85 6,374.67 -5,803.12 -330.71 5,773.76 7.00 90.78 6,019,980.22 516,005.86 16 10,500.00 92.02 242.10 6,373.10 -5,820.89 -366.31 5,797.38 7.00 -100.00 6,019,962.37 515,970.30 10,600.00 90.78 235.21 6,370.65 -5,872.86 -451.63 5,863.23 7.00 -100.11 6,019,910.22 515,885.10 10,660.18 90.03 231.06 6,370.22 -5,908.96 -499.76 5,907.04 7.00 -100.28 6,019,874.02 515,837.05 17 10,700.00 90.51 233.81 6,370.04 -5,933.23 -531.33 5,936.38 7.00 80.00 6,019,849.68 515,805.54 10,800.00 91.72 240.70 6,368.09 -5,987.28 -615.37 6,004.04 7.00 80.01 6,019,795.45 515,721.63 10,810.18 91.84 241.41 6,367.77 -5,992.20 -624.27 6,010.42 7.00 80.15 6,019,790.51 515,712.74 18 10,900.00 90.96 235.18 6,365.57 -6,039.37 -700.63 6,070.00 7.00 -98.00 6,019,743.18 515,636.50 11,000.00 89.96 228.25 6,364.77 -6,101.29 -779.07 6,144.46 7.00 -98.15 6,019,681.10 515,558.20 11,010.18 89.86 227.55 6,364.79 -6,108.11 -786.62 6,152.48 7.00 -98.21 6,019,674.26 515,550.66 19 11,100.00 88.88 233.76 6,365.78 -6,165.03 -856.04 6,220.47 7.00 99.00 6,019,617.19 515,481.37 11,200.00 87.80 240.68 6,368.68 -6,219.12 -940.03 6,288.17 7.00 98.93 6,019,562.92 515,397.52 11,210.18 87.69 241.38 6,369.08 -6,224.04 -948.92 6,294.55 7.00 98.73 6,019,557.98 515,388.63 20 11,300.00 87.71 235.09 6,372.69 -6,271.27 -1,025.19 6,354.16 7.00 -90.00 6,019,510.59 515,312.47 11,400.00 87.76 228.08 6,376.65 -6,333.31 -1,103.43 6,428.72 7.00 -89.75 6,019,448.38 515,234.37 Planned TD at 11400.00 5/14/2014 2:21:41 PM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-14 Survey Calculation Method: Minimum Curvature Wel lbore: 3Q-14A Design: 3Q-14A_wp04 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3Q-14A_T7 0.00 0.00 6,370.00 -8,670.741,139,621.54 6,019,614.00 1,655,848.00 70°13'17.362 N 140°38'32.830 W -plan hits target center -Point 3Q-14A_Fault3 0.00 0.00 0.00 -8,278.901,140,168.45 6,020,007.00 1,656,394.00 70°13'20.354 N 140°38'15.435 W -plan hits target center -Rectangle(sides W295.00 H1.00 D0.00) 30-14 CTD Polygon 0.00 0.00 0.00 -7,162.071,141,211.01 6,021,126.00 1,657,434.00 70°13'29.647 N 140°37'40.649 W plan hits target et center 9 -Polygon Point 1 0.00 -7,162.071,141,211.01 6,021,126.00 1,657,434.00 Point 2 0.00 -7,307.101,141,217.70 6,020,981.00 1,657,441.01 Point3 0.00 -7,448.871,141,103.38 6,020,838.99 1,657,327.01 Point4 0.00 -7,702.981,140,678.80 6,020,583.98 1,656,903.03 Points 0.00 -8,152.701,140,055.77 6,020,132.94 1,656,281.05 Point 6 0.00 -8,540.561,139,508.68 6,019,743.92 1,655,735.07 Point 7 0.00 -8,879.591,139,037.11 6,019,403.89 1,655,264.09 Point 8 0.00 -9,253.631,139,038.31 6,019,029.89 1,655,266.11 Point 9 0.00 -9,026.351,139,383.83 6,019,257.90 1,655,611.10 Point 10 0.00 -8,552.631,140,004.91 6,019,732.94 1,656,231.07 Point 11 0.00 -8,225.581,140,463.66 6,020,060.96 1,656,689.06 Point 12 0.00 -7,706.181,141,234.85 6,020,582.00 1,657,459.03 Point 13 0.00 -7,491.621,141,454.33 6,020,797.02 1,657,678.02 Point 14 0.00 -7,293.75 1141 520.76 6,020,995.01 1 657 744.01 Point 15 0.00 -7,120.641,141,477.13 6,021,168.01 1,657,700.00 Point 16 0.00 -7,162.071,141,211.01 6,021,126.00 1,657,434.00 3Q-14A_Fault4 0.00 0.00 0.00 -8,675.731,139,620.53 6,019,609.00 1,655,847.00 70°13'17.315 N 140°38'32.880 W -plan hits target center -Rectangle(sides W310.00 H1.00 D0.00) 3Q-14A_T1 0.00 0.00 6,408.00 -7,403.421,141,360.50 6,020,885.00 1,657,584.00 70°13'27.082 N 140°37'37.422 W -plan hits target center -Point 3Q-14A_T5 0.00 0.00 6,390.00 -8,081.491,140,447.91 6,020,205.00 1,656,673.00 70°13'21.855 N 140°38'6.558 W -plan hits target center -Point 3Q-14A_Faultl 0.00 0.00 0.00 -7,285.491,141,398.76 6,021,003.00 1,657,622.00 70°13'28.170 N 140°37'35.808 W -plan hits target center -Rectangle(sides W310.00 H1.00 D0.00) 3Q-14A_T3 0.00 0.00 6,359.00 -7,825.191,140,780.51 6,020,462.00 1,657,005.00 70°13'23.849 N 140°37'55.900 W -plan hits target center -Point 3Q-14A_T6 0.00 0.00 6,392.00 -8,298.931,140,183.41 6,019,987.00 1,656,409.00 70°13'20.137 N 140°38'15.094 W -plan hits target center -Point 3Q-14A_T4 0.00 0.00 6,362.00 -7,925.921,140,653.28 6,020,361.00 1,656,878.00 70°13'23.061 N 140°37'59.989 W -plan hits target center -Point 3Q-14A_T2 0.00 0.00 6,376.00 -7,630.961,141,140.97 6,020,657.00 1,657,365.00 70°13'25.199 N 140°37'44.714 W -plan hits target center -Point 3Q-14A_Fault2 0.00 0.00 0.00 -7,824.181,140,775.51 6,020,463.00 1,657,000.00 70°13'23.867 N 140°37'56.038 W -plan hits target center -Rectan•le sides W310.00 H1.00 D0.00 5/14/2014 2:21:41PM Page 6 COMPASS 2003.16 Build 69 C) RI IN L . ...._..___......_._... . . ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Local Co-ordinate Reference: Well 3Q-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-14 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-14A Design: 3Q-14A_wp04 { 9 '4 ..., . ,e ,-,� k ay .,,, :a ,wc., . .11,aa,0.rmsflsse raIMMV1 3Q-14A_T8 0.00 0.00 6,368.00 -9,088.521,139,047.56 6,019,195.00 1,655,275.00 70°13'14.157 N 140°38'51.112 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,400.00 6,376.65 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,200.00 6,374.75 -4,386.00 1,204.44 TIP 8,215.00 6,385.64 -4,395.69 1,207.97 KOP 8,236.00 6,400.52 -4,409.61 1,213.05 End 14 dls,Start 45 dls 8,355.18 6,433.75 -4,512.91 1,250.75 4 8,465.18 6,416.17 -4,617.65 1,241.47 End 45 dls,Start 7 dls 8,535.18 6,408.14 -4,676.37 1,204.26 6 8,835.18 6,376.00 -4,885.01 993.46 7 9,035.18 6,362.00 -4,976.81 816.89 8 9,235.18 6,358.85 -5,069.79 640.41 9 9,385.18 6,362.10 -5,165.70 525.40 10 9,510.18 6,376.22 -5,250.53 434.85 11 9,660.18 6,390.09 -5,347.20 321.27 12 9,860.18 6,391.51 -5,454.41 153.03 13 10,010.18 6,392.17 -5,530.99 24.29 14 10,160.18 6,388.43 -5,629.37 -88.59 15 10,460.18 6,374.67 -5,803.12 -330.71 16 10,660.18 6,370.22 -5,908.96 -499.76 17 I 10,810.18 6,367.77 -5,992.20 -624.27 18 11,010.18 6,364.79 -6,108.11 -786.62 19 11,210.18 6,369.08 -6,224.04 -948.92 20 11,400.00 6,376.65 -6,333.31 -1,103.43 Planned TD at 11400.00 5/14/2014 2.21:41 PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-14 3Q-14A 3Q-14A_wp04 Travelling Cylinder Report 12 May, 2014 BAKER HUGHES _ti. ,,,,:f7,,, ;,La,F ,.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 30-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 30-14 @ 60.00ft(3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 30-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 3Q-14A_wp04 Offset TVD Reference: Offset Datum Reference 3Q-14A_wp04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,200.00 to 11,400.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,334.006 Error Surface: Elliptical Conic Survey Tool Program Date 5/12/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 8,200.00 3Q-14(3Q-14) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,200.00 11,400.00 3Q-14A_wp04(3Q-14A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ('S) (") 11,400.00 6,436.65 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3Q Pad 3Q-06-3Q-06-30-06 Out of range 3Q-06-3Q-06A-3Q-06A Out of range 3Q-06-3Q-06AL1-3Q-06AL1 Out of range 3Q-07-3Q-07-30-07 Out of range 3Q-09-30-09-3Q-09 Out of range 30-13-30-13-30-13 Out of range 3Q-14-3Q-14-30-14 8,225.00 8,225.00 0.12 1.26 -0.81 FAIL-Major Risk 30-14-3Q-14AL1-30-14AL1_wp01 11,396.60 11,400.00 52.77 99.47 -31.29 FAIL-Major Risk 3Q-14-3Q-14AL2-30-14AL2_wp01 10,174.99 10,175.00 0.61 1.51 -0.12 FAIL-Major Risk 3Q-14-3Q-14AL3-30-14AL3_wp01 10,575.16 10,575.00 12.62 28.94 -5.40 FAIL-Major Risk 3Q-14-3Q-14AL4-30-14AL4_wp01 9,324.99 9,325.00 0.47 0.89 -0.25 FAIL-Major Risk 3Q-14-3Q-14AL5-3Q-14AL5_wp01 8,525.00 8,525.00 0.00 0.29 -0.22 FAIL-Major Risk 3Q-22-3Q-22-3Q-22 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 2 of 9 COMPASS 2003.16 Build 69 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 30-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14-3Q-14 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (0) lel (ff) (f1/ Off) ('1 (ft) (ft) (ff) (H) (H) (ff) 8,225.00 6,452.82 8,225.00 6,452.90 0.08 0.22 -19.70 -4,402.15 1,210.33 0.22 0.12 1.26 -0.81 FAIL-Major Risk,CC,ES,SF 8,249.77 6,469.46 8,250.00 6,471.06 0.08 0.44 -19.49 -4,41828 1,216.24 0.22 2.01 2.55 -0.32 FAIL-Major Risk 8,273.08 6,481.86 8,275.00 6,489.21 0.09 0.66 -19.63 -4,434.42 1,222.17 0.22 8.25 4.22 4.23 Pass-Major Risk 8,293.73 6,489.68 8,300.00 6,507.37 0.09 0.88 -19.67 -4,450.54 1,228.12 0.22 18.56 5.71 13.11 Pass-Major Risk 8,311.25 6,493.84 8,325.00 6,525.53 0.10 1.09 -19.69 -4,466.66 1,234.08 0.22 32.16 6.96 25.57 Pass-Major Risk 8,325.80 6,495.48 8,350.00 6,543.68 0.10 1.31 -19.72 -4,482.78 1,240.04 0.22 48.28 7.99 40.83 Pass-Major Risk 8,337.77 6,495.59 8,375.00 6,561.84 0.10 1.53 -19.75 -4,498.90 1,246.01 0.22 66.29 8.86 58.18 Pass-Major Risk 8,347.63 6,494.84 8,400.00 6,579.99 0.11 1.75 -19.77 -4,515.02 1,251.97 0.22 85.73 9.63 77.10 Pass-Major Risk 8,356.31 6,493.55 8,425.00 6,598.15 0.11 1.97 -19.17 -4,531.13 1,257.93 0.22 106.22 10.28 97.20 Pass-Major Risk 8,369.72 6,491.21 8,450.00 6,616.30 0.11 2.19 -11.60 -4,547.25 1,263.90 0.22 127.10 10.54 117.84 Pass-Major Risk 8,382.73 6,488.95 8,475.00 6,634.46 0.12 2.41 -3.81 -4,563.37 1,269.86 022 148.05 11.19 138.54 Pass-Major Risk 8,395.10 6,486.82 8,500.00 6,652.61 0.12 2.63 3.87 -4,579.49 1,275.82 022 169.09 11.85 159.32 Pass-Major Risk 8,397.95 6,486.34 8,506.00 6,656.97 0.13 2.68 5.68 -4,583.36 1,27725 0.22 174.16 12.00 164.33 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 3 of 9 COMPASS 2003.16 Build 69 ORIGINAL IIA ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 30-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 30-14 @ 60.00ft(3Q-14) Site Error: O.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 30-14A Database: EDM Alaska Prod v16 Reference Design: 3Q-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14AL1-3Q-14AL1_wp01 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO,8200-MWD,10750-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 10,774.99 6,428.77 10,775.00 6,428.46 0.41 0.30 -170.94 -5,975.03 -593.55 0.22 0.49 2.33 -1.32 FAIL-Major Risk,CC 10,799.92 6,428.09 10,800.00 6,426.82 0.82 0.59 -169.13 -5,988.53 -614.53 0.22 1.96 4.35 -1.42 FAIL-Major Risk 10,824.84 6,427.32 10,825.00 6,424.43 125 0.87 -166.72 -6,001.99 -635.46 0.22 4.24 6.36 -0.62 FAIL-Major Risk 10,849.79 6,426.63 10,850.00 6,421.28 1.67 1.15 -158.75 -6,015.40 -656.32 0.22 6.74 8.42 1.18 Pass-Major Risk 10,874.66 6,426.05 10,875.00 6,417.37 2.09 1.44 -149.58 -6,028.76 -677.09 0.22 9.71 10.53 4.18 Pass-Major Risk 10,899.43 6,425.58 10,900.00 6,412.95 2.51 1.73 -142.67 -6,042.27 -697.65 0.22 13.28 12.65 8.10 Pass-Major Risk 10,924.15 6,425.22 10,925.00 6,408.52 2.95 2.04 -139.42 -6,056.40 -717.79 0.22 17.14 14.86 12.09 Pass-Major Risk 10,948.83 6,424.96 10,950.00 6,404.10 3.39 2.35 -138.04 -6,071.15 -737.49 0.22 21.18 17.08 16.11 Pass-Major Risk 10,973.47 6,424.81 10,975.00 6,399.68 3.86 2.69 -137.69 -6,086.51 -756.71 0.22 25.37 19.41 20.16 Pass-Major Risk 10,998.07 6,424.77 11,000.00 6,39529 4.34 3.02 -137.95 -6,102.45 -775.46 0.22 29.67 21.74 24.26 Pass-Major Risk 11,022.53 6,424.83 11,025.00 6,390.92 4.85 3.37 -137.19 -6,118.97 -793.71 0.22 34.07 24.21 28.33 Pass-Major Risk 11,046.90 6,425.01 11,050.00 6,387.07 5.38 3.73 -136.32 -6,135.79 -811.80 0.22 38.17 26.76 31.65 Pass-Major Risk 11,071.27 6,425.30 11,075.00 6,383.97 5.99 4.11 -136.58 -6,152.77 -829.88 0.22 41.77 29.51 33.98 Pass-Major Risk 11,095.56 6,425.69 11,100.00 6,381.81 6.61 4.50 -137.77 -6,169.91 -847.92 0.22 44.95 32.22 35.32 Pass-Major Risk 11,119.71 6,42620 11,125.00 6,380.00 7.31 4.92 -139.77 -6,187.18 -865.92 0.22 47.82 35.13 35.67 Pass-Major Risk 11,143.65 6,426.81 11,150.00 6,379.14 8.01 5.34 -142.52 -6,204.58 -883.86 0.22 50.53 37.99 35.18 Pass-Major Risk 11,167.34 6,427.53 11,175.00 6,379.02 8.82 5.79 -145.83 -6,222.01 -901.78 0.22 53.22 41.07 33.98 Pass-Major Risk 11,190.82 6,428.34 11,200.00 6,379.57 9.66 6.26 -14925 -6,239.19 -919.93 0.22 55.96 44.11 32.42 Pass-Major Risk 11,214.44 6,429.25 11,225.00 6,380.78 10.62 6.78 -153.28 -6,256.08 -938.32 0.22 58.78 47.59 30.39 Pass-Major Risk 11,240.01 6,430.28 11,250.00 6,382.64 11.86 7.27 -159.44 -6,272.66 -956.94 0.22 61.12 52.68 26.81 Pass-Major Risk 11,265.92 6,431.32 11,275.00 6,385.17 14.48 7.85 -164.91 -6,288.90 -975.77 022 62.53 61.38 20.01 Pass-Major Risk I 11,292.06 6,432.37 11,300.00 6,388.35 18.03 8.43 -169.89 -6,304.81 -994.79 0.22 62.90 72.46 10.17 Pass-Major Risk 11,318.32 6,433.42 11,325.00 6,392.18 20.34 9.12 -174.57 -6,320.36 -1,013.99 0.22 62.13 80.89 0.70 Pass-Major Risk 11,344.57 6,434.46 11,350.00 6,396.66 22.12 9.80 -179.10 -6,335.54 -1,033.34 0.22 60.20 87.95 -9.17 FAIL-Major Risk 11,370.70 6,435.50 11,375.00 6,401.79 23.34 10.66 176.37 -6,350.34 -1,052.82 0.22 57.07 93.96 -19.67 FAIL-Major Risk 11,396.60 6,436.52 11,400.0 6,407.56 24.41 11.52 171.64 -6,364.74 -1,072.43 0.22 52.77 99.47 -31.29 FAIL-Major Risk,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 4 of 9 COMPASS 2003.16 Build 69 ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(30-14) Site Error: 0.008 North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0.008 Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 30-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14AL2-30-14AL2_wp01 Offset Site Error: 0 00 ft Survey Program: 100-BOSS-GYRO,8200-MWD,10150-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ON/-6 +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (") (ft) (ft) (ft) (ft) (ft) (ft) 10,174.99 6,447.73 10,175.00 6,448.34 0.22 0.17 34.90 -5,639.90 -99.03 0.22 0.61 1.51 -0.12 FAIL-Major Risk,CC,ES,SF 10,199.92 6,446.56 10,200.00 6,448.87 0.45 0.33 57.09 -5,657.72 -116.55 0.22 2.35 2.77 1.03 Pass-Major Risk 10,224.70 6,445.40 10,225.00 6,450.50 0.69 0.50 66.99 -5,675.51 -134.04 0.22 5.38 4.09 3.22 Pass-Major Risk 10,249.23 6,444.26 10,250.00 8,453.21 0.94 0.67 72.84 -5,693.23 -151.47 0.22 9.72 5.40 6.71 Pass-Major Risk . 10,27364 6,443.12 10,275.00 8,456.16 1.20 0.84 76.84 -5,710.61 -169.19 0.22 14.40 6.78 10.52 Pass-Major Risk 10,298.09 6,441.99 10,300.00 6,458.48 1.46 1.01 80.20 -5,727.39 -187.57 0.22 18.48 8.16 13.71 Pass-Major Risk 10,322.57 6,440.86 10,325.00 6,460.18 1.74 1.20 83.41 -5,743.54 -206.58 0.22 21.94 9.59 16.24 Pass-Major Risk 10,347.03 6,439.74 10,350.00 6,461.68 2.01 1.38 85.90 -5,758.90 -226.24 0.22 25.10 11.03 18.49 Pass-Major Risk 10,371.48 6,438.63 10,375.00 6,463.17 2.31 1.58 87.62 -5,773.38 -246.56 0.22 28.08 12.51 20.64 Pass-Major Risk 10,395.90 6,437.53 10,400.00 6,464.66 2.60 1.78 88.80 -5,786.97 -267.49 0.22 30.89 13.98 22.71 Pass-Major Risk 10,420.32 6,436.43 10,425.00 6,466.14 2.91 1.99 89.57 -5,799,62 -289.00 0.22 33.52 15.48 24.69 Pass-Major Risk 10,444.73 6,435.35 10,450.00 6,467.60 3.21 2.20 90.00 -5,811.33 -311.04 0.22 35.99 16.96 26.62 Pass-Major Risk I 10,469.55 6,434.27 10,475.00 6,469.06 3.53 2.41 88.69 -5,822.06 -333.57 0.22 38.26 18.55 28.43 Pass-Major Risk 10,495.04 6,433.28 10,500.00 6,470.49 3.85 2.63 83.31 -5,831.80 -356.55 0.22 39.85 20.28 30.03 Pass-Major Risk 10,520.29 6,432.43 10,525.00 6,471.90 4.16 2.86 75.92 -5,840.56 -379.92 0.22 40.92 21.98 31.83 Pass-Major Risk 10,545.41 6,431.72 10,550.00 6,473.05 4.46 3.08 68.42 -5,849.65 -403.18 0.22 41.91 23.65 33.78 Pass-Major Risk 10,570.50 6,431.15 10,575.00 8,473.82 4.77 3.31 61.65 -5,859.70 -426.05 0.22 42.80 25.32 35.44 Pass-Major Risk 10,595,55 6,430.71 10,600.00 6,474.21 5.08 3.53 55.48 -5,870.68 -448.51 0.22 43.50 26.96 36.38 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 5 of 9 COMPASS 2003.16 Build 69 flJ: ! G ! NAL.- WC- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(30-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(30-14) Site Error: 0.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 30-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14AL3-3Q-14AL3_wp01 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO,8200-MWD,10080-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) )ft) (ft) (ft) 10,099.99 6,450.72 10,100.00 6,450.43 0.17 0.12 -92.87 -5,587.33 -45.59 0.22 0.37 1.36 -0.79 FAIL-Major Rink,CC 10,124.93 6,449.90 10,125.00 6,448.43 0.38 0.26 -94.67 -5,603.58 -64.47 0.22 1.90 2.38 -0.02 FAIL-Major Risk 10,149.74 6,448.90 10,150.00 6,445.34 0.59 0.42 -96.51 -5,619.77 -83.27 0.22 4.58 3.50 1.88 Pass-Major Risk 10,174.52 6,447.75 10,175.00 6,441.20 0.80 0.58 -97.56 -5,635.83 -101.97 0.22 8.29 4.70 4.80 Pass-Major Risk 10,199.37 6,446.59 10,200.00 6,436.71 1.03 0.75 -96.75 -5,651.29 -121.10 0.22 12.33 5.96 8.04 Pass-Major Risk 10,224.27 6,445.42 10,225.00 6,432.23 1.28 0.92 -94.50 -5,665.89 -140.89 0.22 16.57 7.30 11.35 Pass-Major Risk • 10,249.22 6,444.26 10,250.00 6,427.78 1.53 1.10 -91.67 -5,679.59 -161.32 0.22 21.02 8.66 14.78 Pass-Major Risk 10,274.36 6,443.09 10,275.00 6,423.86 1.79 1.28 -88.93 -5,692.97 -182.07 0.22 24.86 10.09 17.55 Pass-Major Risk 10,299.75 6,441.91 10,300.00 6,421.01 2.07 1.46 -86.48 -5,706.59 -202.84 0.22 27.28 11.53 18.91 Pass-Major Risk 10,325.28 6,440.74 10,325.00 6,419.23 2.36 1.65 -84-20 -5,720.41 -223.59 0.22 28.27 13.02 18.79 Pass-Major Risk 10,350.84 6,439.57 10,350.00 6,418.52 2.65 1.84 -82.02 -5,734.42 -24428 0.22 27.83 14.50 1725 Pass-Major Risk 10,376.31 6,438.41 10,375.00 6,418.69 2.95 2.04 -80.44 -5,748.73 -264.78 0.22 25.99 16.02 14.38 Pass-Major Risk 10,401.55 8,437.27 10,400.00 6,418.93 3.26 2.24 -82.23 -5,763.86 -284.68 0.22 23.00 17.51 11.01 Pass-Major Risk 10,426.36 6,438.17 10,425.00 6,419.15 3.57 2.44 -89.79 -5,779.84 -303.90 0.22 19.24 19.03 8.30 Pass-Major Risk 10,450.75 6,435.09 10,450.00 6,419.35 3.88 2.64 -105.24 -5,796.12 -322.87 0.22 16.02 20.50 8.53 Pass-Major Risk 10,475.10 6,434.04 10,475.00 6,419.56 4.19 2.86 -126.10 -5,811.59 -342.50 0.22 14.72 22.12 6.62 Pass-Major Risk 10,499.84 6,433.11 10,500.00 6,419.76 4.50 3.08 -143.26 -5,826.19 -362.79 0.22 14.78 23.83 1.68 Pass-Major Risk 10,524.90 6,432.29 10,525.00 6,419.96 4.80 3.31 -153.57 -5,839.89 -383.70 0.22 14.86 25.54 -1.69 FAIL-Major Risk 10,550.07 6,431.60 10,550.00 6,420.16 5.10 3.54 -157.70 -5,852.67 -405.18 0.22 14.21 27.24 -4.13 FAIL-Major Risk 10,575.16 6,431.06 10,575.00 6,420.36 5.42 3.77 -155.13 -5,864.50 -427.21 0.22 12.62 28.94 -5.40 FAIL-Major Risk,ES,SF 10,580.16 6,430.96 10,580.00 6,420.40 5.48 3.82 -153.55 -5,866.75 -431.67 0.22 1221 29.28 -5.35 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 6 of 9 COMPASS 2003.16 Build 69 14"- ext ., I I FA_ .. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(30-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 30-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 30-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14AL4-30-14AL4_wp01 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO,8200-MWD,9305-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ONl-S +E/-W Hole Size Centre Distance Deviation Off (ft) (ff) (e) (n) In) (1 (ft) ON (H) (n) (n) le) 9,324.99 6,420.00 9,325.00 6,419.59 0.09 0.07 -100.64 -5,124.61 569.30 0.22 0.47 0.89 -0.25 FAIL-Major Risk,CC,ES,SF 9,349.89 6,42074 9,350.00 6,418.68 0.19 0.15 -102.33 -5,140.49 550.02 0.22 2.39 1.66 1.03 Pass-Major Risk 9,374.57 6,421.65 9,375.00 6,416.68 0.30 0.24 -104.04 -5,156.33 530.79 0.22 5.76 2.32 3.95 Pass-Major Risk 9,398.96 6,422.80 9,400.00 6,413.63 0.41 0.33 -105.33 -5,172.10 511.63 0.22 10.53 3.03 8.27 Pass-Major Risk 9,423.24 6,424.56 9,425.00 6,410.98 0.54 0.42 -106.11 -5,187.91 492.44 0.22 15.41 3.81 12.72 Pass-Major Risk 9,447.52 6,426.98 9,450.00 6,409.41 0.67 0.52 -106.44 -5,203.77 473.18 0.22 19.80 4.61 16.68 Pass-Major Risk 9,471.78 6,430.05 9,475.00 6,408.79 0.81 0.62 -106.93 -5,219.71 453.94 0.22 23.78 5.47 20.25 Pass-Major Risk 9,495.81 6,433.72 9,500.00 6,407.86 0.95 0.72 -109.86 -5,236.20 435.18 0.22 28.26 6.33 24.48 Pass-Major Risk 9,520.11 6,437.97 9,525.00 6,406.31 1.09 0.83 -114.50 -5,253.33 417.04 0.22 33.55 7.21 29.65 Pass-Major Risk 9,545.48 6,441.91 9,550.00 6,404.38 1.24 0.93 -119.37 -5,271.07 399.53 0.22 38.68 8.10 34.68 Pass-Major Risk 9,571.21 6,445.11 9,575.00 6,403.10 1.38 1.04 -123.99 -5,289.39 382.57 0.22 42.55 9.02 38.45 Pass-Major Risk 9,597.14 6,447.55 9,600.00 6,402.57 1.53 1.15 -128.83 -5,308.25 366.17 0.22 45.12 9.96 40.86 Pass-Major Risk 9,623.19 6,449.18 9,625.00 6,402.82 1.69 1.26 -133.70 -5,327.31 349.99 0.22 46.51 10.93 41.79 Pass-Major Risk 9,649.37 6,449.99 9,650.00 6,403.85 1.85 1.37 -137.79 -5,345.86 333.28 0.22 46.62 11.92 41.19 Pass-Major Risk 9,674.52 6,450.13 9,675.00 6,405.66 2.01 1.49 -140.76 -5,363.87 316.04 0.22 45.50 12.95 39.22 Pass-Major Risk 9,698.83 6,450.22 9,700.00 6,408.26 2.18 1.61 -143.56 -5,381.30 298.30 0.22 43.83 13.98 36.48 Pass-Major Risk 9,723.03 6,450.34 9,725.00 6,411.37 2.37 1.74 -146.76 -5,398.06 280.01 0.22 41.92 15.08 33.31 Pass-Major Risk 9,747.19 6,450.48 9,750.00 6,414.50 2.55 1.87 -149.93 -5,414.00 261.01 0.22 40.21 16.17 30.22 Pass-Major Risk 9,771.33 6,450.65 9,775.00 6,417.62 2.75 2.01 -153.02 -5,429.09 241.33 0.22 38.66 17.30 27.17 Pass-Major Risk 9,795.44 6,450.85 9,800.00 6,420.72 2.95 2.15 -155.99 -5,443.30 221,00 0.22 37.21 18.43 24.16 Pass-Major Risk 9,819.54 6,451.07 9,825.00 6,423.80 3.16 2.31 -158.81 -5,456.60 200.06 0.22 35.84 19.61 21.14 Pass-Major Risk 9,843.64 6,451.32 9,850.00 6,426.85 3.37 2.46 -161.47 -5,468.98 178.55 0.22 34.49 20.77 18.12 Pass-Major Risk 9,868.23 6,451.60 9,875.00 6,429.86 3.59 2,63 -164.97 -5,480.39 156.52 0.22 33.06 22.00 14.98 Pass-Major Risk 9,893.87 6,451.84 9,900.00 6,432.84 3.81 2,80 -169.49 -5,490.84 134.00 0.22 30,62 23.29 10.98 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 7 of 9 COMPASS 2003.16 Build 69 OR1G ! NA . ...RI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 3Q-14A_wp04 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad- 3Q-14-3Q-14AL5-30-14AL5_wp01 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO,8200-MWD,8525-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) )ft( (ft) P( (ft) (ft) (ft) (ft) (ft) (ft) 8,525.00 6,469.21 8,525.00 6,469.21 0.00 0.00 -145.95 -4,668.02 1,209.98 0.22 0.00 0.29 -0.22 FAIL-Major Risk,CC,ES,SF 8,549.98 6,466.60 8,550.00 6,466.00 0.02 0.06 -175.58 -4,688.56 1,196.10 0.22 0.71 0.91 -0.15 FAIL-Major Risk 8,574.87 6,464.00 8,575.00 6,461.71 0.04 0.07 -175.28 -4,708.97 1,182.31 0.22 2.74 1.23 1.60 Pass-Major Risk 8,599.58 6,461.40 8,600.00 6,456.35 0.07 0.08 -173.97 -4,729.20 1,168.64 0.22 6.07 1.54 4.65 Pass-Major Risk 8,624.04 6,458.80 8,625.00 6,450.03 0.10 0.10 -172.26 -4,749.19 1,155.02 0.22 10.55 1.88 8.85 Pass-Major Risk 8,648.45 8,456.20 8,650.00 6,443.71 0.13 0.12 -170.04 -4,768,68 1,140.70 0.22 14.93 2.22 12.96 Pass-Major Risk 8,672.87 6,453.58 8,675.00 6,437.62 0.16 0.14 -167.58 -4,787.56 1,125.49 0.22 18.93 2.57 16.68 Pass-Major Risk 8,697.29 6,450.95 8,700.00 6,431.93 0.20 0.16 -165.61 -4,805.96 1,109.56 0.22 22.50 2.94 19.98 Pass-Major Risk 8,721.70 6,448.31 8,725.00 6,427.24 0.24 0.18 -166.15 -4,824.47 1,093.42 0.22 25.57 3.35 22.79 Pass-Major Risk 8,745.99 6,445.68 8,750.00 6,423.62 0.28 0.20 -168.72 -4,843.11 1,077.16 0.22 28.27 3.76 25.23 Pass-Major Risk 8,770.15 6,443.06 8,775.00 6,420.74 0.33 0.23 -172.00 -4,861.59 1,060.58 0.22 30.83 4.21 27.20 Pass-Major Risk 8,794.25 6,440.44 8,800.00 6,417.89 0.38 0.27 -174.13 -4,879.35 1,04322 0.22 33.33 4.67 29.18 Pass-Major Risk 8,818.31 6,437.83 8,825.00 6,415.04 0.44 0.31 -175.36 -4,896.32 1,025.09 0.22 35.68 5.16 31.01 Pass-Major Risk 8,842.28 6,435.24 8,850.00 6,412.21 0.49 0.35 -175.93 -4,912.49 1,006.23 0.22 37.83 5.67 32.65 Pass-Major Risk 8,866.09 6,432.83 8,875.00 6,409.15 0.56 0.40 -175.63 -4,927.87 986.77 0.22 40.04 6.20 34.34 Pass-Major Risk 8,889.80 6,430.64 8,900.00 6,405.35 0.63 0.45 -174.06 -4,942.57 966.91 0.22 42.76 6.74 36.56 Pass-Major Risk 8,913.37 6,428.68 8,925.00 6,400.79 0.70 0.50 -171.44 -4,956.57 946.71 0.22 45.98 7.31 39.31 Pass-Major Risk 8,936.83 6,426.94 8,950.00 6,396.38 0.78 0.56 -169.03 -4,970.18 926.21 0.22 49.41 7.89 42.25 Pass-Major Risk 8,960.23 6,425.42 8,975.00 6,393.03 0.86 0.62 -167.80 -4,983.73 905.46 0.22 52.71 8.50 45.00 Pass-Major Risk 8,983.53 6,424.12 9,000.00 6,390.73 0.95 0.69 -167.52 -4,997.16 884.51 0.22 55.89 9.12 47.59 Pass-Major Risk 9,006.76 6,423.04 9,025.00 6,388.78 1.04 0.77 -167.14 -5,009.93 863.11 0.22 58.94 9.78 50.01 Pass-Major Risk 9,029.94 6,422.17 9,050.00 6,386.83 1.13 0.85 -166.27 -5,021.76 841.17 0.22 61.79 10.45 52.23 Pass-Major Risk 9,055.63 6,421.40 9,075.00 6,384.88 123 0.94 -167.47 -5,032.61 818.74 0.22 64.04 11.24 53.78 Pass-Major Risk 9,082.14 6,420.72 9,100.00 6,382.95 1.32 1.04 -168.45 -5,042.47 795.85 0.22 64.82 12.03 53.93 Pass-Major Risk 9,108.54 6,420.14 9,125.00 6,381.03 1.40 1.14 -168.38 -5,051.32 772.55 0.22 64.17 12.84 52.71 Pass-Major Risk 9,134.61 6,419.68 9,150.00 6,379.14 1.50 1.25 -167.08 -5,059.14 748.88 0.22 6221 13.63 50.31 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8.59:29AM Page 8 of 9 COMPASS 2003.16 Build 69 0 R--- 1 GI \ A L_ Fir ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft(3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft(3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 30-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14A Database: EDM Alaska Prod v16 Reference Design: 3Q-14A_wp04 Offset TVD Reference: Offset Datum Reference Depths are relative to 3Q-14 @ 60.00ft(3Q-14) Coordinates are relative to:3Q-14 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.12° Ladder Plot 180 I I I I I I I I I I I I I I I J J J J J __ I i I 1 1 I I 1 I 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C 1 N U I 45—.-- I I J J J J _ J_ I i I I I I I I 0 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND $ 3Q-14,3Q-14,3Q-14 V1 3Q-14,3Q-14AL2,3Q-14AL2 wp01 VO - 3Q-14,3Q-14AL4,3Q-14AL4 vtip01 V0 _• 3Q-14,3Q-14AL1,3Q-14AL1 )4)01V0 -e- 3Q-14,3Q-14AL3,3Q-14AL3_wp01 Vo 3Q-14,3Q-14AL5,3Q-14AL5%p01 VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/12/2014 8:59:29AM Page 9 of 9 COMPASS 2003.16 Build 69 ORIGINA1_ • • w b a 1 i C V c d v :� g F m� I w § v �/ I s 8 N a v al' p G _-- •e grn I a 3. g 6 a v .e €$$; Q1, a1, 8 c`2 : ffi Li 0,pPx I?, _ "E E p u, i ::1 It V en r 311 - $ a Q0.. a V lk Q a g 3 a $ 00 00 0. 1 00 CC 3 (ui/li OOZ) +) oJ(��Ilnos E-I on CO11 a 5 a >> v ID v H g h C) o 27 $ _ i ..8d C of H no g 148 O 10 v v 0 FF E J-_LO mi. 10CL c q CL C C V • � � 01 a H Y W<W N I a0'0 CI_ I I TTFF''jj - M 8 aZ mrONiN mrt NTr cr aO 6^i1 NCI I a� - . 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TRANSMITTAL LETTER CHECKLIST WELL NAME: 1<R u„ 3Q - NA PTD: c2 )1/ 0 /Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: lit I fcN VEf POOL: 1.� I �VEJ' ),kI llAi\ RI'ALF (a/ 1 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. 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