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213-123
Originated: Delivered to:27-Mar-25Alaska Oil & Gas Conservation Commiss27Mar25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDMT7-15 50-103-20885-00-00 224-037 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Feb-251H-106 50-029-23800-00-00 224-117 Kuparuk River WL TTiX-PPROF FINAL FIELD 22-Feb-251C-157 50-029-23754-00-00 223-038 Kuparuk River WL TTiX-FSI FINAL FIELD 27-Feb-25CD3-127 50-103-20634-00-00 211-005 Colville River WL Patch&Packer FINAL FIELD 8-Mar-251C-151 50-029-23497-00-00 213-123 Kuparuk River WL TTiX-FSI FINAL FIELD 12-Mar-253S-624 50-103-20868-00-00 223-104 Kuparuk River WL TTiX-FSI FINAL FIELD 22-Mar-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40238T40239T40240T40241T40242T402431C-15150-029-23497-00-00213-123Kuparuk RiverWLTTiX-FSIFINAL FIELD12-Mar-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.03.28 08:11:16 -08'00' 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Thursday, February 27, 2025 12:12 PM To:Byrne, Jan; Loepp, Victoria T (OGC) Cc:Sumrall, Shelby Subject:RE: KRU 1C-151 (PTD 213-123) Request for short gas lift production period to allow for PPROF Jan, You are approved to flow 1C-151 for up to 14 days with gas lift per the plan below. Thanks, Jack From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, February 27, 2025 11:48 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Sumrall, Shelby <Shelby.Sumrall@conocophillips.com> Subject: KRU 1C-151 (PTD 213-123) Request for short gas lift production period to allow for PPROF Victoria, Jack, KRU 1C-151 (PTD 213-123) is an ESP producer that we currently have need to perform a PPROF on. We plan to pull the ESP and install a GLD to place the well on gas liŌ producƟon for a few days (no more than 7 days total) to allow for running the PPROF while on gas liŌ producƟon. Once the PPROF is complete gas liŌ producƟon will be shut in and the well will be returned to ESP producƟon as soon as possible. We plan to start this work within the next few days. Please advise if this plan for the PPROF is acceptable. Regards, Jan Byrne CPF1 Well Intervention | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Morales, Tony To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Cc:Cozby, Kelly;Henson, James;NSK RWO CM Subject:7ES KRU 1C-151 BOPE Test Date:Monday, May 2, 2022 7:02:39 AM Attachments:Nabors 7ES 04-29-22.xlsx Tony Morales 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 805 797-6720 tony.morales@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. .58& 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:7ES DATE: 4/30/22 Rig Rep.: Rig Phone: 670-6132 Operator: Op. Phone:670-6130 Rep.: E-Mail Well Name: PTD #22131230 Sundry #322-117 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/2500 MASP:1242 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 2 7/8"x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"NA H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2 1/16 Gate P Time/Pressure Test Result System Pressure (psi)2925 P CHOKE MANIFOLD:Pressure After Closure (psi)1560 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 16 P Full Pressure Attained (sec)109 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5@1965 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:7.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4-28-22/ 13:34 Waived By Test Start Date/Time:4/29/2022 19:00:00 PM (date) (time)Witness Test Finish Date/Time:4/30/2022 2:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nabors Tested with 4 1/2" test jnt. Tony Morales / Sean Holcomb ConocoPhillips Mark Adams / Kevin Barr KRU 1C-151 Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0429_BOP_Nabors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y Samantha Carlisle at 9:02 am, Mar 10, 2022 Ron Phillips Digitally signed by Ron Phillips Date: 2022.03.09 15:44:48 -09'00' 10-404 BOP test to 3000 psig Annular preventer to 2500 psig DSR-3/10/22 CO ESP X X SFD X VTL 3/18/2022 SFD 3/10/2022 JLC 3/18/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.18 15:07:36 -08'00' RBDMS SJC 032322 !""! #$ %%$ & '"( '"(!')" #"$*%! # !""! # +$"%,% *$#-$-!%$ # .$ '"( /$ !""! #$0 # !''!1" $#! +$''"#.!#$$ 2/!''!#.#3+$''" # !''!1" '"(2# $$45"-4 !%"# 11'! %! #& -#35 11 *'% 6 ( *$-1-(!*$7!$'38 +$"%( 3- $ 9:/; < +$'' 6"3!''$3#3 1'$%$3!# " != #%'1 3- $6!% " $$#" ""% $+$"%("#3": $ 4>$ %!*$ &% !"+!"% 1-''% $&!'$3 -% &% $#3-##$6 $""!.'$"" 1'$%! # 2&5 - *$#5?-$"%! #" $?-!$#5&-% $!#& %! #1'$"$ #% % $% Ron Phillips Digitally signed by Ron Phillips Date: 2022.03.09 15:45:18 -09'00' 1 3- $6!% " $$#" ""% $+$"%("#3": $ 4>$ %!*$ &% !"+!"% 1-''% $&!'$3 -% &% $#3-##$6 $""!.'$"" 1'$%! # !" !" 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3,995.9 3,580.2 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 10/23/2014 1RWHV *HQHUDO 6DIHW\ (QG'DWH $QQRWDWLRQ 7/31/2014 NOTE: SOV @ 3996' RKB has 2000# TBG Shear +25,=217$/& 30 9HUWLFDOVFKHPDWLF DFWXDO /,1(5 ,17(50(',$7( 6($/$66< /2&$725 1,33/( 6/((9(& 1,33/( 1,33/( 3XPS&DQ$VV\ ,626/((9( 6+528' 6+528' 6+528' 6/,36723 *$8*( *$6/,)7 *$6/,)7 685)$&( 1,33/( &21'8&725 +$1*(5 .83352'& 2‘sk23 2.3l3 Schlumberger Transmittal#: 6631 Drilling & Measurements MWD/LWD Log Product Delivery DATA LOGGED $/'1 /2014 M K BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 1C-151 Date Dispatched: 20-Feb-14 Job#: 13AKA0117 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: Vision Service 2"MD 1 Hardcopy Contents on CD Vision Service 2"TVD 1 Hardcopy Contents on CD Vision Service 5 MD 1 Hardcopy Contents on CD Vision Service 5"TVD 1 Hardcopy Contents on CD LAS Digital Data Contents on CD SURVEY 1 Survey Contents on CD EOW CD RECEIVED1 CD MAR 0 7 2014 ACC Please sign and email a copy to: Please sign and email/fax a copy to: afellAslb.com spacillo@slb.com Stephanie Pacillo Arina Fell Fax:907-561-8317 907-265-6519 ATO 1525 N Received By: • 2..‘ -‘2.3 2'59'13 ECEIVEL MAR 0 7 2014 AOGCC Schlumberger Conoco hilips 1C-151 Definitive Survey Report )Def Survey) Report Dab: January 20,2014-03:03 PM Survey I DLS Computation: Minimum Curvature/Lublnrski Client: ConacoPhSips(Alaska)Inc.-Kuhl Ventral Section Azimuth: 345.000•(True Norm) Field: Kuparuk River Unit Vertical Section Origin: 0.000 R 0.000 R Structure/Slot Kuparuk 1C Pad 1 Plan:10-151 TVD Reference Datum: RKB Wet: 10151 TVD Reference Elevation: 85.700 R above Mesh Sea Level 60Mwle: 10151 Seabed I Ground Elevation: 58.40011 above Mean Sea Level I1NA/APIs: Magnetic Declination: 19.725• Survey Name: 10-151 Definitive Total gravity Field Strength: 1001.9670019n(9.80665 Based) Survey Dab: December 18,2013 Gravity Model: GARM Tort I AND/DDI I ERD Ratio: 223.888•/9756.778 6/8.858/2.554 Tool Magnetic Field Strength: 57819.635 nT CeoNkiete Reference System: NA027 Alaska State Rana,Zone 04,US Feet Magnetic Dip Angle: 80.932• Location Lat I Long: N 70.18 32.2614T,W 149.28 52.40788• Declination Data: November 23.2013 Location Grid N/S WK.: N 5968922.980 BUS,E 581919.480 BUS Magnetic Dec5naton Model: BGGM 2013 CRS Grld Convergence Angle: 0.4728• Norm Reference: True Norm Grid Scale Factor. 0.99990438 Grid Convergence Used: 0.0000• Version/Patch: 2.7.7043.0 Total Con Mag NOM->7rue 197248• NOM: Local Coord Referenced To: Wel Head Comment MD True 1V Mel Azlm 05S TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude 441 71 /1 (13) (B) ttl Ili (ft) (M (M 71156.11 fBUSI IftUSI P1 In RTE 0.00 0.00 0.00 -85.70 0.00 0.00 0.00 0.00 0.00 0.00 N/A 5868922.96 561919.48 70,32562817 -149.49789107 27.30 0.00 0.00 -58.40 27.30 0.00 0.00 0.00 0.00 0.00 0.00 5968022.98 581919.48 70.32582817 -149.49789107 181.48 0.25 80.58 95.78 181.46 0.08 0.34 0.34 0.17 0.29 0.18 5968923.13 561919.75 70.92562862 -149.49788870 207.11 0.19 158.36 121.41 207.11 0.06 0.41 0.39 0.15 0.36 1.30 5968923.12 581919.82 70.32582859 -149.49788817 264.17 0.14 150.14 178.47 284.17 .0.11 0.58 0.43 0.00 0.43 0.10 5968922.97 581919.89 70.32562819 -149.49788761 313.14 0.11 148.41 227.44 313.14 -021 0.68 0.49 -0.09 0.48 0.06 5968922.88 581919.94 70.32562794 .149.49788718 357.73 0,98 318.20 272.93 957.73 0.06 1.04 0.30 0,17 0.25 248 5968923.13 561919.71 70.32562863 -149.49786905 405.76 2.80 325.25 320.03 405.73 1.49 2.54 1.52 1,37 -0.05 3.38 5968924.32 561918.60 70.32563192 -149.49789832 447.92 3.50 327.25 382.13 447.83 3.62 4.78 3.75 3.24 -1.89 2.15 5968926.18 561917.54 70.32563702 -149.49790839 497,27 4.25 327.34 411.37 497.07 6.79 8.12 7.08 8.04 -3.69 1.52 5968928.97 561915.72 70.32564489 -149.49792100 539.48 4.47 326.51 453.44 538.14 9.84 11.32 10.29 5.73 -5.44 0.54 5968931.65 561913.95 70.32505203 -149.49799519 589.89 6.17 330.47 503.65 589.35 14.33 16.00 14.96 12.73 -7.86 3.45 5888935.82 581911.49 70.32586295 -149.49795482 833.40 7.51 331.62 546.85 632.55 19.36 21.18 20.14 17.27 -10.37 3.10 5868940.14 581908.95 70.32567534 -149.49797512 881.06 9.03 334.97 594.01 679.71 26.07 26.03 26.96 23.39 -13.43 3.34 5988948.24 561905.84 70.32589209 -149.49799996 726.50 9.61 335.72 838.85 724.55 33.33 35.39 34.31 30.08 -18.50 1.30 596895290 561902.72 70.32571038 -149.49802494 818.99 10.28 339.93 729.95 815.65 49.15 51.34 50.18 44.88 -22,50 1.05 6868967.63 561896.59 70.32575072 -149.49807350 912.33 9.61 339.88 821.89 907.59 65.19 67.45 86.21 59.98 -28.03 0.70 5968982.70 561890.94 70.32579204 -149.49811838 1005.12 10.00 334.55 913.33 999.03 80.83 83.24 61.98 74.53 -34.16 1.06 6988997.20 681884.69 70.325133178 .149.49818803 1098.02 8.96 328.34 1004.98 1090.68 95.62 98.44 97.16 57.90 41.38 1.54 9969010.01 561877.36 70.32588832 -149.49822659 1189.57 9.21 331.48 1095.39 1181.09 109.49 12.82 111.48 100.34 48.58 0.86 5969022.89 561870.06 70.32590230 -149.49828496 1282.77 7.76 332.67 1187.57 1273.27 122.89 28.57 125.22 112.48 -55.03 1.57 5969034.98 561863.51 70.32593547 -149.49833726 1376.06 5.16 328.12 1280.26 1365.96 133.06 37.06 135.70 121.64 80.14 2.84 5969044.09 561858.33 7032596049 -149.49077858 1468.51 4.82 324.81 1372.19 1458.09 710.69 45.10 741.68 128.35 84.57 0.48 5969050.70 561653.84 70.32597682 -U8.49841484 1561.52 5.34 333.20 1465.00 1550.70 148.59 53.32 167.87 175.11 -08.77 0.97 5989057.78 561649.58 70.32599809 -149.49844871 1654.09 5.48 340.96 1557.16 1642.88 157.22 02.03 160.56 143.43 -72.15 0.80 5969085.77 581846.13 70.32802001 -149.49847618 1748.91 5.84 954.72 1649.55 1735.25 166.13 70.98 189.21 15218 -74.02 1.44 6869074.49 581/344.19 70.32604388 -149.49849128 183923 4.15 347.19 1741.53 1827.23 173.94 78.85 178.72 159.94 -75.18 1.75 596808225 581842.97 70.32608510 -149.49850068 1932.19 5.80 348.06 1834.15 1919.85 181.83 913.75 184.43 157.65 -76.87 1.58 5969089.98 581841.22 70.32608619 -149.49851433 2024.79 8.24 341.10 1928.28 2011.98 191.37 96.29 193.86 176.83 -79.43 1.04 5968039.12 561838.56 70.32617727 -149.49861573 2716.94 6.95 347.31 2017.81 2103.51 201.85 06.79 204.31 786.78 82.87 0.88 5969108.03 581835.12 70.32613844 -149.49856254 2210.82 9.26 344.31 2110.76 2196.48 214.99 19.94 217.37 199.38 86.65 2.80 5989121.58 561831.18 70.12617280 -149.49859383 2302.88 11.50 338.29 2201.31 2287.01 231.51 36.51 233.69 215.02 -92.05 2.70 5969137.19 561825.65 70.32621558 -149.49863741 2395.58 14.71 351.11 2291.60 2377.30 252,40 57.45 254.56 235.24 -97.28 4.65 5969157.37 56182025 70.32627083 -149.49667990 2422.64 15.78 351.88 2317.71 2403.41 259.47 264.56 281.47 242.27 -98.33 3.95 5969164.39 561819.14 70.32629004 -149.49868841 1338•Surface 2454.25 18.80 350.82 2346.07 2433.77 288.22 273.37 270.05 250.98 .99.66 2.82 5969179.09 561817.74 70.32631383 .149.49869917 Cas6p 2521.78 18.41 348.87 2412.47 2498.17 288.48 293.88 28998 270.97 -103.26 2.82 5969193.04 581813.98 70.32638843 -149.49672634 2536.93 19.14 348.32 2428.81 2512.51 293.33 298.55 294.79 275.75 -10422 4.98 5909187.81 581812.97 70.32638149 -149.49873617 2628.93 21.53 350.68 2513.07 2598.77 325.19 330.52 326.29 307.18 -110,01 2.75 5969229.19 561806.93 70.32646736 -149.49878310 2722.64 23.84 351.24 2599.53 2885.23 381.13 366.65 381.88 342.87 -115.68 2.48 6969264.83 581800.96 70.32858487 -149.49882908 2814.45 27.04 350.07 2882,42 2768.12 400.37 406.09 400.83 381,76 -122.11 3.53 5969303.513 561794.22 70.32867115 -149.49888119 2907.32 30.29 348.89 2753.90 2819.80 444.78 450.83 445.05 425.56 -130.26 3.55 5969347.39 581785.70 70.92878077 -149.49694733 2999.73 32.94 348.22 2842.58 2928.29 493.12 499.08 493.28 473.03 -139.89 299 5969394.78 561775.89 70.32692046 -149.49902535 3093.36 35.98 347.75 2920.06 3005.76 545.82 551.63 545.71 524.45 -150.84 2,52 5989418.10 561764.32 70.32706093 -149.49911415 3165.87 38.61 34725 2993.84 3079.54 801.35 007.42 601.40 578.91 .162.92 3.72 5969500.45 561751.79 70.32720971 -149.49921215 3279.02 41,83 347.83 3084.98 3150.66 081.44 667.56 681.45 837.64 -175.89 3.05 5809559.07 561738.34 70.32737015 -149.49931731 3371.74 45,00 347.18 3132.41 3218.11 724.97 731.16 724.98 899.73 -189.66 3.87 5969621.03 561724.05 70.32753977 -14949942899 1 Drilling Office 2.7.1043.0 Kuparuk River UnitlKuparuk 1C Pad11 C-151\1C-15111 C-151 Definitive 1/21/2014 8:00 AM Page 1 of 3 • C9ntmerMs MD incl A2are True TVDSS TVD VSEC ABS Closure NS EW DLS Northing Eaatin8 Latitude Longitude IRI (1 (1 (M (M MM MI IM MI (ft) maim MUS) MUST in II 3483.71 48.06 347.61 3195.68 3281.38 791.85 797.90 791.65 764.80 -204.22 3.34 5969088.03 581708.90 70.32771770 -149.49964705 3558.93 50.47 347.47 3256.50 3342.20 882.22 868.53 882.22 833.83 -219.46 2.59 5969754.87 581893.15 70.32790611 -149.49967055 3849.75 53.56 347.54 3313.82 3399.32 935.29 941.68 935.32 905.24 -235.28 333 5959826.14 581076.74 70.32810121 -149.49979600 3742.82 56.75 349.54 3358.80 3452.50 1011.51 1016.05 1011.58 960.08 -250.43 3.85 5969800.66 561880.98 70.32830589 -149.49992185 3835.33 59.44 352.13 3415.89 3501.39 1089.62 1095.57 1089.80 1057.81 28291 3.70 5989078.28 501647.86 70.32551747 -149.50002308 ` 3928.70 61.10 351.70 3481.99 3547.89 1170.11 1177.65 1170.48 1137.88 -274.31 1.82 5970056.43 561535.79 70.32873578 -149.50011559 4020.65 62.20 352.10 3505.88 3591.30 1250.42 12511.57 1251.04 7218.02 -265.50 1.37 5970138.47 587823.94 70.32685570 -149.30020035 4119.21 62.01 352.11 3548.96 3834.86 1337.56 1340.38 1332.49 1298.08 -280.57 0.32 5970218.43 581612.27 70.32917715 -149.50029581 4205.55 82.13 351.86 3592.21 3877.01 1412.54 1421.96 1413.80 1379.68 -307.86 0.30 5970300.11 581600.25 70.32939781 -149.50038771 4297.37 53.87 351.57 3834.04 3719.74 1493.72 1503.70 1495.32 1480.76 319.64 1.70 5970380.89 581587.81 70.32981883 -149.50048327 4389.74 70.80 350.62 3669.76 3755.46 1578.35 1588.52 1580.30 1544.85 -332.83 7.78 5970464.80 561573.92 70.32984555 -149.50059030 4482.31 77.75 349.90 3694.81 3780.51 1887.34 1677.87 1869.28 1832.82 -347.91 7.58 5870552.49 581558.12 70.33008833 -149.50071200 4574.39 84.07 351.38 3709.33 3795.03 1757.48 1758.75 1760.06 172219 -383.70 7.01 5970842.03 561542.60 70.33033330 -149.50083254 4688.70 85.82 350.42 3717.80 3803.50 1850.90 1882.68 1853.88 1815.03 -377.57 1.92 5970734.63 581526.97 70.330581135 -149.93095319 4750.33 88.79 347.32 3723.87 3809.57 1942.11 1954.11 1945.30 190472 395.22 3.81 5970824.17 551508.58 70.33083169 -149.50109635 9598 (6Mudiate 4823.45 88.34 347.29 3726.55 3812.25 2005.12 201717 2008.35 1966.24 109.08 2.46 5970885.57 561494.21 70.33098975 -149.50120880 Casing 4858.39 89.15 347.27 3727.27 3812.97 2038.03 2050.10 2041.27 1998.37 -416.33 2.46 5970917.03 551468.70 70.33108751 -149.50126763 4951.27 90.27 347.64 3727.75 3813.45 2132.82 2144.98 2136.14 2090.98 -438.94 1.24 5971010.08 581465.33 70.33134052 -149.50143481 5046.45 90.87 347.44 3728.97 3812.67 2227.90 2240.15 2231.31 2183.91 -457.47 0.47 5971102.81 561444.03 70.33159440 -149.50180140 5141.50 91.18 346.99 3725.45 3811.15 2322.87 2335.19 2328.34 2276.50 4178.50 0.70 5971155.31 581422.24 70.33184760 -149.50177202 5236.50 90.95 348.81 3723.70 3809.40 2417.80 2430.18 2421.30 2389.11 -500.03 0.29 5971287.63 561399.95 70.33210033 -149.50194668 5330.81 89.77 348.07 3723.11 3808.81 2511.88 252418 2515.37 2480.59 -522.10 1.48 5971378.92 561377.13 70.33235025 -149.50212569 5424.81 88.89 343.90 3724.21 3809.91 2806.06 2618.47 2809.43 2551.56 -548.50 2.49 5971469.88 581351.98 70.33259877 -149.50232385 5519.89 87.96 340.38 3728.83 3812.53 2700.97 2713.52 2703.99 2642.01 -57534 3.83 5971559.87 581322.10 70.33284586 -149.50258009 5814.47 89.41 335.31 3729.00 3814.70 2794.78 2808.07 2797.18 2729.55 -411.29 5.57 5971847.11 581285.73 70.33308501 -149.50284928 5707.27 81.28 327.54 372845 3814.15 2884.89 2900.80 2885.43 2810.98 -855.84 8.61 5971728.16 581240.72 70.33330746 -149.50320906 5802.22 90.90 327.55 3728.116 3812.36 2975.45 2995.00 2976.18 2891.09 -706.58 0.38 5971807.84 581189.12 70.33352629 -149.50382234 5898.40 91.08 327.18 3725.04 3810.74 3065.19 3089.96 305542 2970.39 -757.36 0.44 5971886.71 561137.69 70.33374291 -149."461.912 5992.07 90.98 326.51 3723.32 3809.02 3156.09 3185.62 3158.09 3050.47 .809.08 0.71 5971966.35 561084.72 70.33395187 -149.50445872 6086.73 9017 328.79 3722.12 3807.82 3245.92 3280.27 3246.00 3129.53 -881.71 0.81 5972044,97 561032.04 70.33417785 -149.50488088 8181.02 90.48 327.07 3721.34 3807.04 3335.56 3374.58 3335.98 3208.55 -913.10 0.30 5972123.55 560979.95 70.33439349 -149.50529826 6275.30 90.87 329.14 3720.23 3805.93 3425.70 3488.83 3426.37 3288.58 -962.97 2.23 5972203.15 500929.45 70.33481211 -149.50570239 636941 91.19 331.25 3718.53 3804.23 3516.73 3562.92 3518.24 3370.22 -1009.74 2.27 5972284.41 560882.05 70.33483515 -149.50608184 8483.32 91.09 333.81 3716.67 3802.37 3808.39 3656.82 3810.50 3453.52 -1053.01 2.73 5972387.34 580838.06 70.33508270 -149.50543323 8559.27 91.50 336.17 3714.50 3800.20 3702.85 3752.74 3705.50 3540.45 -1093.80 2.50 5972453.92 560790.80 70.33530015 -149.50676229 6652.52 90.70 338.44 3712.70 3798.40 3795.54 3846.27 3798.60 3828.73 -1129.68 2.57 5972539.89 560780.01 70.33553580 -149.50705511 8749.19 90.34 340.25 3711,83 3797.53 3891.43 3942.64 3894.80 3716.90 -116387 1.91 597262977 550725.27 70.33575218 -149.50733096 8841.86 90.71 342.43 3710.98 3798.88 3983.70 4035.11 3987.24 3804.50 -1193.25 2.39 5972717.11 550894.97 70.33002148 -149.50757106 l 6937.43 88.81 343.74 3711.55 3797.25 4079.41 4130.87 4083.00 3896.12 -1221.12 2.58 5972808.49 5808311.36 70.33027176 -149.50779720 7031.94 88.47 345.76 3713.96 3799.66 4173.88 4225.35 417740 3987.27 -1245.96 2.14 5972899.42 560840.76 70.33652078 -149.50799891 712716 8833 347.64 3718.87 3802.57 4269.11 4320.62 4272.44 4079.90 -1267.88 2.02 5972991.94 560818.08 70.33677404 -149.50817684 7222.15 88.07 348.89 3719.60 3805.30 4363.81 4415.47 4366.66 4172.85 -1287.17 1.48 5973084.84 580596.03 70.3315[7(4 -149.50833347 7317.80 88.53 350.07 3721.94 3807.64 4459.13 4511.09 4481.85 4288.86 -1304.83 1.24 5973178.49 580579.80 70.33728456 -149.50847523 7412.16 58.45 352.10 3724.42 3810.12 4552.92 4605.42 4555.26 4360.04 -131915 2.15 6973271.54 560564.41 70.33753912 .148.50859395 750.5.48 69.73 355.49 3725.91 3811.51 4845.12 4698.73 4645.98 4452.79 -1329.33 3.88 5973364.19 560553.56 70.33778249 -149.50867589 7800.72 59.77 357.59 3728.32 3812.02 473843 4793.97 4739.73 4547.85 -1335.08 2.21 5973459.19 580547.03 70.33805218 -149.50872265 7395.55 89.60 355.95 3726.84 3812.54 4831.26 4880.80 4832.18 4642.52 -1340.42 1.74 5973553.81 56054091 70.33831082 -149.50875014 7790.26 90.17 353.76 3727.03 3812.73 4924.57 498350 4925.17 4736.85 -1348.91 2.39 5977348.05 580531.64 70.33856850 -149.50883518 7884.97 90.18 352.44 3726.74 3812.44 5018.33 507821 5018.73 4830.87 -1360.29 1.39 5973741,97 500519.49 70.33882535 -149.50892763 7979.44 90.24 352.35 3726.40 3812.10 5112.01 5172.68 5112.27 4924.51 -1372.79 0.11 5973835.49 560506.21 70.33908115 -149.50902920 8074.53 90.03 351.62 3726.17 3811.87 5208.40 5267.77 5208.55 5018.87 -1388.05 0.80 5973929.53 560492.18 70.33933838 -149.50913891 8188.21 89.76 350.84 372834 3812.04 5299.52 5381.45 5299.80 5111.25 -1400.34 0.88 5974021.98 560477.14 70.33959131 -149.50825294 8233.27 89.72 350.86 3728.78 3812.48 5394.09 5456.51 5394.12 5205,10 -1415.45 0.05 5974115.89 580481.25 70.33984789 -149.50937573 8358.03 8968 351.29 3727.29 3812.99 5488.31 5551.27 5488.32 5298.71 -1430.15 0.48 5974209.17 580445.78 70.34010342 -149.50949516 8453.08 89.80 350.04 3727.74 3813.44 5582.89 5648.32 5582.89 5392.50 -1445.57 1.32 5974302.82 580429.59 70.34035983 -149.50902040 8547.34 89.75 348.71 3728.11 3813.81 5678.88 5740.58 5676.88 5465.14 -1462.95 1.41 5974395.31 560411.45 70.34061271 -149.50978156 8842.58 89.68 348.01 3728.60 3814.30 5771.88 5835.80 5771.90 5578.55 -1481.43 0.23 5974488.55 560392.20 70.39486788 -149.50991164 8738.23 89.82 348.73 3729.02 3814.72 5835.35 592917 5885.38 5670.44 -1499.59 026 5874580.25 580373.28 70.34111891 -149.51005918 8832.01 89.98 348.53 3729.21 3814.91 5980.93 5025.25 5980.99 5769.34 -1518.47 015 5074674.01 560353.83 70.34137543 -149.51021253 8928.70 90.60 347.79 3728.74 3814.44 3055.48 811993 0055.55 5857.01 -1537.90 1.03 5974756.51 560333.44 70.34182659 -149.51037033 9021.52 91.57 347.52 3726.95 3812.65 6150.18 6214.74 6150.28 5949.62 -1558.17 1.06 5974858.94 560312.41 70.34188158 -149.51053495 9115.18 91.72 347.00 3724.28 3509.96 8249.71 6308.34 6243.82 6090.92 -1578.61 0.68 5974950.06 580291.01 70.34213089 -149.51070281 9210.45 91.01 348.69 3721.99 3807.89 8336.93 8403.81 6339.08 8133.09 -1600.49 0.81 5975042.64 580268.57 70.34238442 -149.51087871 9306.21 90.10 348.18 3721.05 3800.78 8434954 8499.38 6434.79 6226.76 -1622.95 1.09 5975135.51 580245.35 70.34283587 -149.51106111 9402.44 90.05 348.13 3720.94 3806.84 6530.85 8595.58 6531.01 6320.20 -1845.98 0.07 5975228.74 560221.55 70.34289391 -149.51124814 9497.00 90.10 345.89 3720.81 3806.51 3625.40 0890.14 6625.67 8411.95 -1688.84 0.28 5975320.30 550197.94 70.34314457 -149.51143381 9592.00 89.75 346.22 3720.94 3808.64 8720.38 6755.14 8720.56 8504.15 -1691.73 0.51 5975412.30 560174.29 75.64938449 -149.51181977 9388.08 89.48 348.64 3721.57 3807.27 6814.41 6679.20 6814.81 8595.58 -1713.80 0.53 5975503.54 580151.47 70.34384820 -149.51179903 9781.03 89.45 347.29 3722.43 3808.18 6909.32 6974.17 6909.54 6388.10 -1735.22 0.69 5975595.87 580129.29 70.34359504 -149.51197303 9878.01 89.56 348.21 3723.28 3808.98 7004.19 7069.14 7004.44 6780.92 -1755.37 0.98 5975688.50 550108.37 70.34415249 -149.51213674 9970.27 89.68 349.08 3723.02 3809.62 7098.25 7163.40 7098.55 6873.33 -1773.93 0.93 5975780.75 530089.05 70.34440494 -149.51228753 10085.28 89.38 350.85 3724.48 3810.18 7192.90 7258.41 7199.28 6986.88 -1790.48 1.80 5975874.15 560071.73 70.34488050 -149.51242206 10159.78 89.83 351.50 3725.07 9810.77 7286.85 7352.91 7387.33 703020 -1809.98 0.09 5975967.40 560056.46 70.34491559 -149.51253989 10253.33 89.55 351.59 3725.86 3811.38 7379.78 744813 7380.37 7152.82 -1818.49 0.42 5970059.84 560042.19 70.34518847 -149.51264974 10348.23 89.42 351.32 3726.43 3812.13 7474.03 7541.35 7474.77 7248.70 91832.35 0.85 5975153.59 560027.56 70.34542493 -149.51273237 10444.08 89.86 350.65 3727.19 3812.89 7569.35 7637.20 7570.23 7341.37 -1847.37 0.74 5976248.12 560011.76 70.34538353 -149.51288445 Drilling Office 2.7.1043.0 Kuparuk River Unit\Kuparuk 1C PadN C-151\1C-15111 C-151 Definitive 1/21/2014 8:00 AM Page 2 of 3 9. MD Incl Adm True TVDSS ND VSEC AHD Closure NS EW DLS Northing Esstlfg Latitude Longitude Comments Int PI 19 (ft) (n) IM Int Ihl (R1 M1 7/10081 MUS) 8tl151 VI II 10538.42 89.52 349.80 3727.79 3813.49 7683.29 7731.54 7684.30 7434.33 -1863.38 0.90 5970340.94 559994,98 70.34593750 -149.51301482 10632.90 89.70 349.01 3728.35 3814.05 7757.49 7820.02 7758.61 752720 -1880.75 0.84 5976433.85 559976.85 70.34819119 -149.51315580 10727.48 90.00 348.88 3728.55 3814.25 7851.95 7920.80 7853.13 7619.65 -1900.87 2.49 5978525.93 559950.17 70.34844375 -14951331761 10822.42 90.17 348.40 3728.36 3814.06 7946.86 8015.54 7946.07 7711.99 -1922.77 0.32 5978818.07 559933.32 70.34669597 -149.51349716 10918.96 90.84 346.76 3727.52 3813.22 8041.35 8110.07 8042.80 7803.94 -194471 0.80 5976709.83 559910.62 70.34694717 -149.51367544 11009.41 91.45 347,15 3725.68 3811.38 8133.73 8202.50 8135.02 7993.99 -1965.57 0.78 5976799.69 559889.02 70.34719315 -149.51384497 11103.43 91.47 347.13 3723.28 3808.98 8227.66 8296.49 8228.99 7985.82 -1988.49 0.03 5978891.14 559887.34 70.34744347 -149.51401496 11198.23 90.05 348.45 3722.00 380770 8322.40 8391.28 8323.77 8077.90 -2008.15 1.63 5978983.23 559844.92 70.34769555 -149.51419098 11294.89 90.62 345.10 9721.41 3807.11 8418.84 8487.74 8420.22 8171.41 -2031.80 1.45 5977078.53 559820.50 70.34795100 -149.51438317 11388.45 90.70 346.41 3720.36 3806.05 8510.59 8579.49 8511.97 8280.35 -2054.33 1.36 5977185.27 559797.24 70.34819398 -149.51458825 11484.24 90.51 348.27 3719.32 3805.02 8608.35 8877.28 8809.78. 8355.37 -2077,43 0.24 5977260.09 559773.37 70.34845333 -149.51475391 11575.69 89.93 344.92 3718.96 3804.68 8700.99 8769.93 8702.40 8445.10 -2100.47 1.59 5977349.82 559749.58 70.34869666 -149.51494120 11673.73 89.37 345.39 3719.55 3805.25 8797.82 8806.77 8799.23 8538.71 -212528 0.75 5977443.01 559724.00 70.34895436 -149.51514281 11788.94 80.97 347.24 3720.90 3806.80 8891.00 8959.97 8892.42 802926 -2147.33 2.03 5977533.37 55970121 70.34920172 -149.51532199 11882.83 90.83 347.72 3721.24 3800.94 6986.79 9055.65 898628 8722.87 -2168.12 1.80 5977628.79 569879.65 70.34945742 -149.51549094 11954.69 90.82 348.47 3720.08 3805.78 9078.51 9147.70 9080.07 8812.74 92187.07 0.84 5977718.50 559859.97 70.34970294 -149.51564497 12049.4 89.35 347.44 3719.94 3805.84 9173.13 9242.45 9174.77 8905.40 -2206.64 1.89 5977808.98 559639.43 70.34995807 -149.51580569 12145.28 88.29 346.34 372191 3607.61 9268.89 9338.27 9270.57 8998.72 -2228.57 1.59 5977902.11 559016.93 70.35021099 -149.51598234 12240.10 88.82 350.88 3724.30 3810.00 9363.48 9433.06 938528 9091.59 -2247.47 4.59 5977984.81 559597.28 70.35048487 -149.51613594 12332.81 87.99 351.43 3726.88 3812.58 9455.84 9525.73 9467.59 9183.13 2281.89 1.22 597808822 559582.10 70.35071475 -149.51623327 12428.40 87,78 350.89 3730.41 3818.11 9550.82 9621.26 9552.76 9277.52 -2276.57 0.61 5978190.47 559500.64 70.35097260 -148.51637287 12503.34 88.15 350.78 3733.07 3818.77 9525.12 9696.15 9527.41 9351.46 -2288.50 0.52 5978254.30 559554.10 70.35117458 -149.51046969 41/2*Liner 1254600 88.15 350.76 3734.45 3820.15 90667.54 9738.79 9669.91 9393.54 2295.33 0.00 5976295.33 559546.93 70.35128955 -14951852526 Prot to 139 12584.00 88.15 350.78 3735.03 3820.73 9385.4 9750.78 9587.85 9411.30 -229821 0.00 5978314.06 559543.90 70.35133806 -149.51664870 Sunray Type: Def Survey Survey Error Model: ISCWSA Rev 0111'3-D 95.000%Confidence 2.7955 dgme Survey Program: MD From MD To EOU Ftey Hole 5W Cuing Diameter Description Pert (R) (m (R) (Int (M) Survey Tool Type Borehole/Survey 1 0.000 27.400 Act Stns 30.000 30.000 GVD-GC-SS-Depth Only 1C-151/1C-151 DefinMw 1 27.400 2422.840 Act Sten 30.000 30.000 OYD-GC-SO 1C-151/10.151 Definitive 1 2422.040 2530.930 Act Sins 30.000 30.000 1909-TREND 1C-151/1C-151 Definitive 1 2538.930 12564.000 Act 5115 30.000 30.000 MWDNFR-A1CLAZSC 1C-151/10.151 Definitive Legal Description: Northing 71) &toting DO 30,100.:3968.4 FSL 4385.7 FEL 612 711N R10E UM 5968922.960 581919.480 BHL 2817 FSI.1378 FEL 35 T129 510E510 5978314.060 559543.900 Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have Men achieved. 0 Yes O No 1 have checked to tin host of my a6Dty Mat the following data k correct: 17 Surfers Coordinates 0 Oe0Mellon&Convergence 17+ GRS Survey Come/ions ❑+ Sunny Tool Codec ,/I SLB DE: V�Q�1t�,. 1>Q✓aQ4�1(LO Client Representative: /1 2'wc�'Ii,� �Gi�I G° 1--(:'(." 1( - ij - �C/Ly DM.: n�" /)7�Q n 210 2-0 1 L Drilling Office 2.7.1043.0 Kuparuk River Unit\Kuparuk 1C Pad\1 C-151\1C-151\1C-151 Definitive 1/21/2014 8:00 AM Page 3 of 3 - RECEIVED STATE OF ALASKA JAN 31 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION ,w, 1a.Well Status: �iYELL COMPLETION OR RECOMPLETIOuNREPORT ANROQAC Gas ❑ ❑ ❑ Abandoned ElSuspendedEl lb.Well Class: 20AAC 25.105 20AAC 25.110 Development El • Exploratory ❑ GINJ ❑ WINJ El WAG ❑ WDSPL ❑ Other El No.of Completions: Service El StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: January 1,2014 • 213-123/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 December 1,2013 50-029-23497-00- 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1313'FNL,4366'FEL,Sec. 12,T11N,T10E,UM December 17,2013 • ( t,... 1C-151 - Top of Productive Horizon: 8.KB(ft above MSL): 86'RKB 15.Field/Pool(s): 484'FSL,541'FWL,Sec. 1,T11 N, R10E,UM GL(ft above MSL): 58'AMSL • Kuparuk River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 2462'FNL, 1378'FEL,Sec.35,T12N, R10E, UM 12544'MD/3820'TVD' West Sak Oil Pool ' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-561919 y- 5968923 Zone-412564'MD/3821'TVD' ADL 25649,25638 , TPI: x-561530 y- 5970716 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-559544 y- 5978314 Zone-4 nipple @ 506'MD/506'TVD 467,463 18.Directional Survey: Yes'Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1795'MD/1783'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Density/Neutron not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 28' 106' 28' 106' 40" 384 sx ArcticSet 1 13.375" 68# L-80 27' 2454' 27' 2434' 16" 1377 sx ALC,275 sx Class G 9.625" 40# L-80 26' 4823' 26' 3812' 12.25" 60 bbls Class G 4.5" 11.6# L-80 4614' 12546' 3800' 3821' 6.75" screened 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/TVD) 4.5" 4660' 4614'MD/3800'TVD / 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. +.`i-/ILI Was hydraulic fracturing used during completion? Yes❑ NoE 1 L DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) in the flowback stage Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El - Sidewall Cores Acquired? Yes ❑ No ❑ , If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBFAME: MAR 207 , c.....,ln_nn7 ao..ieo.i 1nion10 rnr.ITiw icn nM DM/CDCC ,`ILS. 44/22 hy • 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes O No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1795' 1783' needed,and submit detailed test information per 20 AAC 25.071. Top West Sak D sand 4650' 3802' Bottom West Sak D sand 8822' 3815' N/A Formation at total depth: West Sak D 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. ^ C) Contact: David Lee @ 263-3741 Email: David.L.Lee conocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature 0s4..L Phone 265-6120 Date ((jr(2't 4— V 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 ND 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 ` i KUP PROD 1 C-1 51 Conor P1iIIips o Well Attributes Max Angle&MD TD Alaska,Inc. - Wellbore API/UNA Field Name Wellbore Status ncl I") MD(ftKB) -Act BOO(ftKB) 4y,,,x,dob 500292349700 WEST SAK PROD 12,564.0 .". Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-1C-151.10120142:0907 PM SSSV:NIPPLE Last WO: -31.10 1/1/2014 Venaal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag- Rev Reason:NEW WELL haggea 1/31/2014 HANGER;23.3 #CUT. Casing Strings if 1r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread 11 .An(-r CONDUCTOR 20 19.124 27.7 106.3 106.3 94.00 K-55 Welded lS' Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread SURFACE 133/8 12.415 27.0 2,454.2 2,433.7 68.00 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 25.8 4,823.4 3,813.3 40.00 L-80 Hydril 563 CONDUCTOR;27.7-106.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtLen(1...Grade Top Thread LINER 412 4.000 4,614.2 12,546.0 3,821.2 11.60 L-80 Hydril 563 • NIPPLE;505.7 Liner Details Nominal ID • Top(ftKB) Top(TVD)(ftKB) Top Incl(.) Item Des Corn (in) 4,6142 3,800.0 84.72 PACKER BAKER ZXP LINER TOP PACKER 7.375 SURFACE;27.0-2,454.2-A 1 4,633.0 3,801.7 85.03 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 6.180 4,635.9 3,801.9 85.08 HANGER BAKER FLEX-LOCK LINER HANGER 6.190 4,647.1 3,802.8 85.26 SBE BAKER SEAL BORE RECEPTALE 4.750 GAS LIFT;2,491.1 4,668.4 3,804.5 85.61 VALVE BAKER FLCV 4.600 4,938.3 3,814.6 90.12 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 GAS LIFT;3,996.9 PACKER OD -- 5,015.5 3,814.1 90.54 TRACER TRACERCO CATRIDGE 1-925,TRACERO T-720 4.950 GAUGE;4.051.6CATRIDGE 11 5,046.7 3,813.7 90.67 SCREEN BAKER EXCLUDER 2000 ULTRAFINE SCREEN 4.000 - } (107 MICRON) SHROUD 83;4,092.7 6,219.2 3,807.7 90.64 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 TUBING STOP:4,101.8- r_::I PACKER OD SHROUD 82;1,108.3, SLEEVE;4,103.0 7 1/II, 6,293.2 3,806.7 90.93 TRACER TRACERCO CATRIDGE T-913,TRACERO T-165H 4.950 SHROUD#1;4.120.0 !I�_ CATRIDGE PUMP;4,133.8` • MOTOR;4.125.8 � ` 6,324.3 3,806.2 91.04 SCREEN BAKER EXCLUDER 2000 ULTRAFINE SCREEN 4.000 DR GAUGE;4,171.9-. �-- (107 MICRON) NIPPLE;4,175.5 n , 7,499.5 3,812.6 89.65 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 i PACKER OD NIPPLE;4,184.5 7,576.4 3,813.0 89.76 TRACER TRACERCO CATRIDGE T-911,TRACERCO T-169B 4.950 SLEEVE-0;4,225.8 - CATRIDGE J 7.607.6 3,813.1 89.76 SCREEN BAKER EXCLUDER 2000 ULTRAFINE SCREEN 4.000 (107 MICRON) NIPPLE;4,279.3 Z 8,783.1 3,815.9 89.89 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 PACKER OD 1' 8,860.2 3,815.9 90.15 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 (; PACKER OD LOCATOR;4,x40.4 8,937.1 3,815.4 90.71 TRACER TRACERCO CATRIDGE T-916,TRACERCO T-165F 4.950 CATRIDGE SEAL ASSY;4,641.0 S a 8,968.3 3,814.9 91.03 SCREEN BAKER EXCLUDER 2000 ULTRAFINE SCREEN 4.000 (107 MICRON) 10,043.9 3,811.1 89.66 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 PACKER OD 10,118.5 3,811.6 89.64 TRACER TRACERCO CATRIDGE T-921,TRACERCO T-165A 4.950 CATRIDGE INTERMEDIATE,268-A523 4-+ . 10,149.6 3,811.8 89.63 SCREEN BAKER EXCLUDER 2000 ULTRALINE SCREEN 4.000 11,238.5 3,808.6 90.31 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 PACKER OD 11,315.5 3,807.9 90.64 TRACER TRACERCO CATRIDGE T-926,TRACERCO T-716 4.950 CATRIDGE 11,346.5 3,807.6 90.67 SCREEN BAKER EXCLUDER 2000 ULTRAFINE SCREEN 4.000 (107 MICRON) 12,434.7 3,817.4 87.81 SWELL SWELL PACKER TAM FREECAP I FSC-124 6.38" 4.540 PACKER OD 12,497.4 3,879.6 88.12 BUSHING BAKER PACKOFF BUSING 2.380 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 23.3 4,659.9 3,803.9 12.60 L-80 IBT Completion Details Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl I") Item Des Com (in) 23.3 23.3 0.03 HANGER CAMERON TUBING HANGER 3.958 505.7 505.4 4.42 NIPPLE CAMCO DB NIPPLE 3.875 4,051.6 3,606.6 61.70 GAUGE BAKER HUGHES GAUGE CARRIER SurSENS gauges 3.879 4,092.7 3,626.1 61.91 SHROUD#3 ESP MOTOR SHROUD#3 3.958 4,106.3 3,632.5 61.98 SHROUD#2 ESP MOTOR SHROUD#2 3.958 4,120.0 3,638.9 62.02 SHROUD#1 ESP MOTOR SHROUD#1 3.958 4,733.5 3,645.4 62.04 PUMP PUMP CAN ASSY-SIDE POCKET w/wet connect 3.958 4,175.5 3,664.9 62.09 NIPPLE ALC B PROFILE NIPPLE 3.926 lig 4,184.5 3,669.1 62.10 NIPPLE ALC NO-GO PROFILE NIPPLE 3.800 3.812 4,225.8 3,688.4 62.47 SLEEVE-0 BAKER CMD SLEEVE run in open position 4,279.3 3,712.7 63.37 NIPPLE CAMCO DB NIPPLE 3.75" 3.750 3.880 4,640.4 3,802.3 85.15 LOCATOR BAKER LOCATOR 4,641.0 3,802.3 85.17 SEAL ASSY BAKER PBR 192-47 3.880 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection WIRELINE 3.72 4,101.8 4,179.6 3,666.8 DEPLOYED ESP MOTOR LINER.4.614.2-12.546 0 KUP PROD 1C-151 ConocoPhillips `' „ Alaska,Inc. ttarnaWtAII11X„ry r ••• HORIZONTAL-1C-151,101/20142:09:09 PM Vertical schematic(actual).. HANGER;23.3 :a .::. Completion Details In Jr Nominal ID Top(HKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) JOINTS W/Protector 375 4,103.0 3,630.9 61.96 SLEEVE ALC ISO SLEEVE-CLOSED 0.000 • 4,125.8 3,641.6 62.03 MOTOR ALC MOTOR HEAD ANDY 0.000 series,MOTOR SUMP,PLUG ARM ASSY. 4,171.9 3,663.2 62.09 DH GAUGE ALC DOWN HOLE GAUGE AND MOTOR GUIDE CONDUCTOR;27.7-106.3 Mandrel Inserts NIPPLE;505.7 St • ati C No Top(TVD) Valve Latch Port Size TRO Run • • Top(HMI) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,491.1 2,468.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/29/2013 SURFACE;270-2.454.2—0 2 3,995.9 3,580.2 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 12/29/2013 • STS-1 GAS LIFT;2.491.1 Notes:General&Safety End Date Annotation NOTE. GAS LIFT;3.995.9 GAUGE;4,051.6 SHROUD#3,4,092.7- I` TUBING STOP 4,101.8 SHROUD#2,4,106.3, I SLEEVE;4.103.0 sj': SHROUD#1,4,120.0 PUMP;4.133.8 •.. i MOTOR,4.125.8 DH GAUGE;4.171.9, :AG NIPPLE,4,175.5 NIPPLE;4,184.5 SLEEVE-0;4,225.8 NIPPLE;4,279.3 to at LOCATOR;4.640.4 .Ip SEAL ASSY;4,641.0 • INTERMEDIATE;25.8-4,823.4—.4 1 LINER,4,614.2-12.546.0 ConocoPhillips Time Log & Summary Wellvrew Web Reporting Report Well Name: 1C-151 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 11/30/2013 12:00:00 AM Rig Release: 1/1/2014 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth-.Phase Code Subcode T Comment 11/28/2013 24 hr Summary Rig released from 2T-41 @ 14:00. Separate mods, crane remove diverter components.4 mods on road @ 19:00. 14:00 16:00 2.00 0 0 MIRU MOVE DMOB P Blow down steam,water and cold starts. 16:00 16:30 0.50 0 0 MIRU MOVE DMOB P PJSM-Jack up pipe sheds 16:30 17:30 1.00 0 0 MIRU MOVE DMOB P Jack up pipe sheds, unplug rig. 17:30 18:00 0.50 0 0 MIRU MOVE DMOB P Move pipe sheds to 2A pad. 18:00 19:45 1.75 0 0 MIRU MOVE DMOB P Jack up modules, move boiler and motor complexes to 2A pad. 19:45 21:15 1.50 0 0 MIRU MOVE DMOB P Move pump and pit complexes to 2A pad. 21:15 21:45 0.50 0 0 MIRU MOVE DMOB P Move rig off well. 21:45 23:30 1.75 0 0 MIRU MOVE DMOB P Start moving all complexes to 1C, SIMOPS clear around well to get crane spotted to pick diverter components. 23:30 00:00 0.50 0 0 MIRU MOVE DMOB P Spot crane 11/2972013 Move rig to 1C-151 and accept 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Continue moving complexes to 1C pad. R/U crane and remove conductor line from under pipeline to the pad on 2T. 03:30 08:30 5.00 0 0 MIRU MOVE MOB P Move sub and pipesheds from 17.2 _ miles from 2T to 1C-151 08:30 11:30 3.00 0 0 MIRU MOVE MOB P Spot sub over well 1C-151 11:30 13:00 1.50 0 0 MIRU MOVE MOB P Lay matting boards 13:00 15:00 2.00 0 0 MIRU MOVE MOB P Continue laying matting boards for _ complexes. 15:00 16:00 1.00 0 0 MIRU MOVE MOB P Lay Herculite,set rockwasher. 16:00 17:45 1.75 0 0 MIRU MOVE MOB P Set matting boards, set pipesheds and shim. Send trucks back for camp. 17:45 00:00 6.25 0 0 MIRU MOVE RURD P PJSM-Hook up electrical connections,steam Water and air service loops.Work on rig acceptance checklist, calibrate and test gas alarms, R/U skate and cattle shute. Rig accept @ 00:00 11/30/13. SIMOPS move camp from 2T to 1C. 11/30/2013 Rig up and function test diverter. Pick up DP, HWDP, Flex collars, Jars, BHA.Tag at 82'RKB. Page 1 of 34 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 SURFA( DRILL NUND P PJSM-N/D diverter,weld conductor groove to establish seal. SIMOPS, take on spud mud. Rig accepted at 00:00 hrs. 03:00 04:00 1.00 0 0 SURFA( DRILL NUND P PJSM-N/U Diverter,test starting head seals to 500 psi(Good)Weld on 6 retainer clips. 04:00 09:00 5.00 0 0 SURFA( DRILL NUND P Continue N/U Diverter,tighten all bolts, set bell nipple. Dress shakers with 105/84 mesh screens. Set up portable Tiogas on pipe shed due narrow ally for trucks. Load pipeshed with 75 jts 5" DP. 09:00 09:45 0.75 0 0 SURFA( DRILL RURD P PJSM, clean and clear rig floor. 09:45 12:00 2.25 0 0 SURFA( DRILL SVRG P PJSM-C/O saver sub, bell guide and grabbers on top drive system. SIMOPS, check pressure on Koomey bottles. 12:00 13:00 1.00 0 0 SURFA( DRILL SVRG P Continue C/O Saver sub,grabbers. 13:00 14:15 1.25 0 0 SURFA( DRILL BOPE P PJSM, change out handling tools to 5", P/U Jt 5"DP,function test accumulator, Diverter test. System pressure=3000 psi, Pressure after closing= 1800 psi.200 psi recovery= 42 seconds, Full recovery= 168 seconds. Knife valve open= 11 seconds, Bag closed=21 seconds.5 bottle average=2000 psi. No failures. AOGCC Jeff Turkington waived witness of test. 14:15 14:45 0.50 0 0 SURFA( DRILL RURD P Strap and number 5" DP and HWDP in pipe shed. 14:45 19:30 4.75 0 0 SURFA( DRILL PULD P PJSM-P/U 25 stands 5"DP via mouse hole and stand back. 19:30 20:45 1.25 0 0 SURFA( DRILL PULD P PJSM-Load jars&BHA in the pipe shed. SIMOPS spot pipe shed Tioga on mats, rack back Jar stand. 20:45 22:15 1.50 0 0 SURFA( DRILL RURD P PJSM-Mobilize BHA tools to the rig floor,thaw same. Obtain RKB measurements. 22:15 23:00 0.75 0 0 SURFA( DRILL PULD P M/U BHA#1. 23:00 00:00 1.00 0 82 SURFA( DRILL PRTS P RIH and tag @ 82' RKB. Flood conductor with water, no leaks. Test surface lines to 3500 psi 5 min. Spud in@00:00. 12/01/2013 Spud at 00:00,drill to 223'MD ROP— 10-15 fph. Inspect bit OK, make up remaining BHA and drill to 402' MD. ROP picked up to acceptable rate at 275'MD. 00:00 11:00 11.00 82 223 SURFA( DRILL DRLG P Spud well,drill ice plugs and cement from 82'to 108'MD,400 gpm @ 300 psi. Continue drilling to 223'MD Varying rates from 400-560 gpm, 500 psi. P/U=42k, 5/0=45k, ROT=45k, TQ on/off 1/1k,WOB'0-2k, ART=9.01. Page 2 of 34 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 223 41 SURFA( DRILL TRIP P POOH t/41'MD, Calc Fill=3.34 bbl, Actual Fi11=3.5 bbl. Drain stack before pulling BHA to surface. 12:00 14:15 2.25 41 223 SURFA( DRILL PULD P PJSM, M/U MWD BHA per SLB, inspect bit,slight clay balling but otherwise OK. 14:15 15:30 1.25 223 223 SURFA( DRILL PRTS P Shallow test MWD and Gyro tools. 15:30 00:00 8.50 223 402 SURFA( DRILL DDRL P Drilling from 223'MD to 402'MD, 401.99'TVD.ART=1.79,AST=1.87, ADT=3.66,Jar Hrs=0, Bit Hrs=12.67, P/U=63k, S/O=63k, ROT=63k, TQ on/off=1/1k, Flow out=88%, WOB=5-30k, 450-500 gpm @ 600-875 psi, 50 rpm. ROP picked up from 10-20 to 50+at 275'MD. Varying WOB and flow,sliding ratio to achieve build angle. 12/02/2013 Directional Drill 16"surface hole per plan,varying pump rates and WOB for directional control. Survey at 45' intervals as required. Hydrates starting at 1160'MD. 00:00 06:00 6.00 402 622 SURFA( DRILL DDRL P PJSM-Drill from 402'MD to 622'MD, 621'TVD,ART=.74,AST=3.03, ADT=3.77, Bit hrs=15.45, P/U=70k, S/O=70k, ROT=71k,TQ on/off= 4/1k, Flow out=77%,WOB=25-30, 50 rpm, 550 gpm @ 950 psi. 06:00 12:00 6.00 622 864 SURFA( DRILL DDRL P Drill from 622'MD to 864' MD, 857' TVD,ART=1.86,AST=1.79, ADT=3.65,Jars hrs=1.95, Bit hrs=19.1, P/U=77k, 5/0=80k, ROT=81 k,TQ on/off=5/1k, Flow out=86%,WOB=25-30, 50 rpm, 700 gpm @ 1550 psi. 12:00 18:00 6.00 864 1,233 SURFA( DRILL DDRL P PJSM-Drill from 864'MD to 1233' MD, 1223'TVD,ART=.3.04, AST=.66,ADT=3.7, Jar hrs=5.65, Bit hrs=22.8, P/U=87k, S/0=83k, ROT=86k,TQ on/off=6/1.5k, Flow out=86%,WOB=25-30, 50 rpm, 600 gpm @ 1150 psi. ECD 10.17 ppg EMW. Started noticing Gas Hydrates at 1160'MD. 18:00 00:00 6.00 1,233 1,511 SURFA( DRILL DDRL P Drill from 1233'MD to 1511'MD, 1500'TVD,ART=.2.16,AST=1.58, ADT=3.74,Jar hrs=9.48, Bit hrs=26.63, P/U=92k, 5/0=90k, ROT=92k,TQ on/off=4/1 k, Flow out=86%,WOB=20-30, 50 rpm,600 gpm @ 1350 psi. ECD 10.12 ppg EMW. Continuing to see Gas Hydrates breaking out at surface. MI treating with Lecithin. 12/03/2013 Directional Drill 16"surface hole per plan to TD,2466'MD, 2445'TVD. BROOH to HWDP, RIH to condition mud. Page 3 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 1,511 1,883 SURFA( DRILL DDRL P Drill from 1511'MD to 1883'MD, 1870'TVD,ART=2.78,AST=1.76, ADT=4.54,Jar hrs=14.02, Bit hrs=31.17, P/U=101k, S/0=100k, ROT=95k,TQ on/off=5.5/1 k, Flow out=78%,WOB=20-25, 50 rpm, 600 gpm @ 1350 psi. ECD 10.23 ppg EMW. 06:00 12:00 6.00 1,883 2,211 SURFA( DRILL DDRL P Drill from 1883'MD to 2211'MD, 2198'TVD,ART=2.09,AST=0.92, ADT=3.01,Jar hrs=16.71, Bit hrs=33.86, P/U=105k, S/0=100k, ROT=105k, TQ on/off=5/2k, Flow out=80%,WOB=25-30, 50 rpm,650 gpm @ 1650 psi. ECD 10.46 ppg EMW. 12:00 17:30 5.50 2,211 2,466 SURFA( DRILL DDRL P Drill from 2211'MD to 2466'MD, 2445'TVD,ART=2.17,AST=1.44, ADT=3.61,Jar hrs=20.32, Bit hrs=37.47, P/U=115k, S/0=105k, ROT=110k,TQ on/off=5.5/4k, Flow out=79%,WOB=10-30, 50 rpm, 660 gpm @ 1675 psi. ECD 10.38 ppg EMW. 17:30 17:45 0.25 2,466 2,466 SURFA( DRILL DDRL P Gyro survey on bottom. 17:45 19:30 1.75 2,466 2,350 SURFA( CASING CIRC P CBU x2 @ 600 gpm, 1300 psi, 50 rpm, 3k TQ, racking back 2 stands. 19:30 22:30 3.00 2,350 850 SURFA( CASING REAM P PJSM, BROOH @ 600 gpm, 50 rpm, 2-10k TQ, slowing to 450 gpm, 725 psi. Cal= 17 bbl,Act=58.55 bbl.42 bbl losses most or all over shakers. 22:30 23:00 0.50 850 850 SURFA( CASING OWFF P Monitor well(hydrates breaking out @ surface,slight flow), Circ 180 bbls @ HWDP,600 gpm, 1100 psi, slowing pump to 450 gpm,725 psi. Monitor well(Hydrates breaking out @ surface,slight flow @ 9.4 ppg). 23:00 00:00 1.00 850 1,233 SURFA( CASING TRIP P B/D top drive. PJSM, RIH on elevators to 1233'MD, P/U 90k, S/O 85k. 12/04/2013 Condition mud and POOH. Run 13-3/8"casing. Cement Surface casing and land on depth. 00:00 00:30 0.50 1,233 2,441 SURFA( CASING TRIP P PJSM, Cont to RIH from 1233'MD to 2441'MD, P/U= 115k, S/O= 101k. Cal= 10.1 bbls,Act-11.0 bbls. 00:30 03:45 3.25 2,441 2,441 SURFA( CASING REAM P M/U top drive break circ wash and ream to 2466'MD, stage up pumps to 500 gpm, reduce pump to 300 gpm, 550 psi,shakers overloading, tag btm(x4), rack back stand to 2441'MD, cont to circ and condition mud at 2441'MD, rack back stand to 2349'MD, cont to circ at 500 gpm, 1000 psi. 03:45 06:00 2.25 2,441 773 SURFA( CASING TRIP P POOH on elevators to 773'MD, monitor well(static). Cal=-34.4 bbls,Act=-40.6 bbls Page 4 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:45 1.75 773 211 SURFA( CASING TRIP P Cont to POOH, Rack back 6 stands HWDP, 1 stand NM Flex DC's. 07:45 09:45 2.00 211 0 SURFA( CASING PULD P Drain stack, Cont L/D BHA from 211' MD. 09:45 10:30 0.75 0 0 SURFA( CASING RURD P Clean&clear rig floor. L/D tools. 10:30 11:30 1.00 0 0 SURFA( CASING RURD P R/U flush stack, make dummy run, fill stack. 11:30 12:00 0.50 0 0 SURFA( CASING RURD P R/U Casing eqpt. 12:00 13:45 1.75 0 0 SURFA( CASING RURD P PJSM, Cont R/U casing eqpt. 13:45 20:30 6.75 0 1,883 SURFA( CASING RNCS P PJSM, Run 13-3/8"casing per detail, M/U float shoe, float collar, M/U 1st joint Hydril 563, observed TQ not up to 25k, call town for decision, decision made to RIH as long as TQ of 22k is achieved. RIH to joint 47 @ 1883' MD, P/U 140 k, S/0 115k. 20:30 21:00 0.50 1,883 1,883 SURFA( CASING CIRC P CBU staging pumps from 2 bpm to 6 bpm, 250-350 psi from 19%to 55% flow out. 21:00 23:30 2.50 1,883 2,454 SURFA( CASING RNCS P Cont RIH w/casing from 1883'MD to 2424'MD. M/U hanger and landing joint, P/U=205k, S/0 150k, Land hanger on depth Shoe depth 2454' MD. Had to drain stack, pull pipe to NW with tuggers to get landed, hanging up on lower diverter flange. Total Calc=58.16 bbl,Actual=51.6 bbl, 56 bow spring centralizers ran. 23:30 00:00 0.50 2,454 2,454 SURFA( CASING RNCS P Rig down Franks Tool, B/D Top Drive. 12/05/2013 Land hanger and cement casing. N/D Diverter, N/U wellhead and test void. Confirm cement top,tag @ 3'. Safety Stand down 30-45 minutes each crew. 00:00 00:45 0.75 2,454 2,454 SURFA( CEMEN-RURD P PJSM, R/U cement head and Circulation valves. 00:45 01:15 0.50 2,454 2,454 SURFA( CEMEN-RURD T Pull hanger to rig floor install centralizer on hanger pup joint. Attempt to land casing hanger, using tuggers to align, pulled master bushing for additional throw. 01:15 02:45 1.50 2,454 2,454 SURFA( CEMEN-CIRC T Break circ,stage pump up to 4 bpm, 300 psi. Loss of 27 bbls.Attempt to land casing hanger, use tuggers to align. 02:45 03:15 0.50 2,454 2,454 SURFA( CEMEN RURD T Drain stack and wash down, land casing using tuggers to align with visual. P/U=205k, S/0= 150k. 03:15 08:00 4.75 2,454 2,454 SURFA( CEMEN CIRC P Break circulation and condition mud, stage up pump to 7 bpm,400 psi. No losses. Page 5of34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 2,454 2,454 SURFA( CEMEN-CMNT P PJSM, Pump cement per plan, pump 10 bbls CW 100 spacer, PT lines to 3000 psi, pump 41 bbls 10.5 ppg Mudpush, shut down, drop bottom plug, pump 465 bbls 11.0 ppg ALC lead cement. Shut down, batch up tail cement.total losses while pumping cement=38 bbls. 12:00 14:00 2.00 2,454 0 SURFA( CEMEN-CMNT P PJSM, Cont pumping cement per plan, 79 bbl 12.0 ppg Tail CMT, drop top plug chase with 10 bbl water. Displace cement @ 8 bpm, 600 psi, plug bumped @ 3410 strokes, pressure up 500 psi over FCP, hold for 5 minutes, bleed pressure& check floats(GOOD). 124bbl ,cement returns to surface. During displacement of cement to bump plug, observed returns were lost, hanger flutes plugged and super sucker was utilized as a contingency per the well program, super sucker hose failed resulting in spill. 14:00 16:00 2.00 0 0 SURFA( CEMEN"RURD P PJSM, R/D cement head, landing head, landing joint&riser,flush diverter bag, clear rig floor. SIMOPS: N/D diverter lines. 16:00 20:30 4.50 0 0 SURFA( CEMEN-RURD P PJSM, N/D diverter, clear cellar area of diverter equipment, bring in wellhead equipment.Tag cement @ 3'from hanger. 20:30 21:15 0.75 0 0 SURFA( CEMEN-RURD P Confirm cement at 3',clear tools from rig floor. 21:15 22:00 0.75 0 0 SURFA( CEMEN-SFTY X Safety stand down with day crew, DDI safety rep, Company reps, Tour Pusher. Reviewed the days incidents. Talked about the spill causes and lessons learned,then finger injury lessons and mitigation. 22:00 00:00 2.00 0 0 SURFA( CEMEN-NUND P PJSM, N/U wellhead and test void to 250 low 5 min, 5000 psi 10 minutes. 12/06/2013 N/U BOP and test. M/U BHA and single in hole. 00:00 03:30 3.50 0 0 SURFA( CEMEN-NUND P PJSM, N/U double flange adaptor spool&BOPE. Install choke line. 03:30 04:00 0.50 0 0 SURFA( CEMEN'SFTY X Safety stand down meeting w/ Company Rep. 04:00 07:00 3.00 0 0 SURFA( CEMEN-RURD P PJSM, R/U BOPE test eqpt. Bad seal on test plug, P/U spare test plug. Page 6 of 34 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 07:00 11:30 4.50 0 0 SURFA( CEMEN-BOPE P Test BOPE, Test all choke valves& rams to 250 psi low and 3500 psi high,test annular to 2500 psi.#1 Top pipe rams,valves 1,12,13,14 and manual kill;#2 Upper IBOP, HCR kill,valve 9, 11;#3 Lower IBOP, Valves 5,8,10;#4 Dart valve,valves 4,6,7;#5 floor valve and valve 2;#6 HCR choke,4"kill line DEMCO valve;#7 Manual choke valve, HCR kill;#8 Annular preventer;#9 Lower pipe rams;#10 Blind Rams, Valve 3; System Pressure 3000 psi, pressure after closed 1700 psi,200 psi attained-56 sec,full pressure attained-219 sec, nitrogen bottle average-2000 psi, all tests w/5" joint. BOPE test witness waived by AOGCC Lou Grimaldi. 11:30 12:00 0.50 0 0 SURFA( CEMEN RURD P R/D test egpt, set 12.322"wear ring. 12:00 13:45 1.75 0 0 SURFA( CEMEN'RURD P PJSM, Cont R/D test egpt, B/D choke lines, choke manifold&kill line, R/U 5"handling tools. 13:45 15:30 1.75 0 0 SURFA( CEMEN PULD P PJSM, R/U to pick up DP. P/U and rack back 21 joints of 5"DP. 15:30 20:00 4.50 0 760 SURFA( CEMEN'PULD P PJSM, M/U BHA per SLB Rep. PJSM, Load nuclear sources. 20:00 20:45 0.75 760 946 SURFA( CEMEN-PULD P PJSM, RIH w/5"DP from shed to 946'MD. 20:45 21:15 0.50 946 946 SURFA( CEMEN-CIRC P Shallow Pulse Test MWD @ 600 gpm, 1250 psi, B/D top drive. 21:15 21:45 0.50 946 946 SURFA( CEMEN-SVRG P Service rig,top drive&draw works. 21:45 23:00 1.25 946 2,284 SURFA( CEMEN-PULD P RIH w/5"DP from shed from 946' MD to 2150' MD, RIH f/Derrik to 2242' MD.Wash down to 2284'at 170 gpm,400 psi.Tag cement stringers at 2284'MD. Calc Disp=29.3 bbl,Actual Disp=32.2 bbl. 23:00 00:00 1.00 2,284 2,340 SURFA( CEMEN TRIP P Drill/wash cement stringers from 2284' MD to 2340'MD at 600 gpm, 1550 psi, 650 gpm @ 1700 psi, 30 rpm,torque erratic between 2-17k ft/lbs. P/U=117k, S/O=92k. 12/07/2013 Casing test. Drill out and perform FIT, directional drill ahead to 3695'MD,3430'TVD. 00:00 00:15 0.25 2,340 2,365 SURFA( CEMEN REAM P PJSM, ream from 2284'MD to 2365' MD @ 710 gpm, 1900 psi, 30 rpm, TQ=2-9k. 00:15 00:30 0.25 2,365 2,365 SURFA( CEMEN'RURD P Rig up to perform casing test 00:30 01:00 0.50 2,365 2,365 SURFA( CEMEN'PRTS P Test casing to 3000 psi for 30 min, charted 99.7%. (SIMOPS, Safety Stand Up with oncoming crew to review recent incidents, Co Rep and Tour Pusher) Page 7 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 2,365 2,365 SURFA( CEMEN-RURD P Rig down test equipment and blow down 01:15 01:30 0.25 2,365 2,367 SURFA( CEMEN-REAM P Ream from 2365'MD to 2367'MD @ 700GPM, 1900psi, 30RPM,TQ=2-5K 01:30 03:45 2.25 2,367 2,430 SURFA( CEMEN-DRLG P Drill out shoe track from 2367'MD to 2430'MD @ 600-700GPM, 1500psi, TQ=2-10K 03:45 04:15 0.50 2,430 2,430 SURFA( CEMEN-CIRC P Mud running over shakers, pick up off bottom and circulate and condition mud system. 04:15 04:30 0.25 2,430 2,466 SURFA( CEMEN-DRLG P Continue to drill shoe track and clean out rat hole from 2430'MD to 2466'MD 04:30 04:45 0.25 2,466 2,486 SURFA( CEMEN'DRLG P Drill 20'new hole from 2466'MD to 2486'MD @ 700GPM, 150psi, 30RPM, TQ=2-5K, pick up weight 120K,slack off weight 100K, rotating weight 110K 04:45 05:00 0.25 2,486 2,486 SURFA( CEMEN'CIRC P Circulate bottoms up @ 700 GPM, 1550psi, 30RPM,TQ=2-5K, 75% flow 05:00 05:15 0.25 2,486 2,486 SURFA( CEMEN'RURD P Blow down at TD, rig up to perform L.O.T. 05:15 05:30 0.25 2,486 2,486 SURFA( CEMEN-LOT P Perform charted LOT, 9.3 ppg mud wt. (EWM= 14.0 ppg) 05:30 05:45 0.25 2,486 2,486 INTRM1 DRILL RURD P Rig down test equipment and blow down 05:45 06:15 0.50 2,486 2,486 INTRM1 DRILL CIRC P Move fluid around in pits to make room for displacement 06:15 07:30 1.25 2,486 2,486 INTRM1 DRILL CIRC P PJSM, pump 25bbls of hi-vis spacer pill,displace out old mud to 9.2 ppg LSND @ 6 BPM,270 psi, 10 RPM, TQ=5K, (obtain SPR's) Pump#1-30 spm @ 130 psi,40 spm @ 170 psi. Pump#2-30 spm @ 130 psi,40 spm @ 170 psi. 07:30 12:00 4.50 2,486 2,802 INTRM1 DRILL DDRL P Drilling from 2486'MD to 2802'MD TVD=2760',ART=1.03,AST=1.12, ADT=2.18,Total jar hours 39.68, Bit hours 2.18, P/U=123K, 5/0=105K, ROT=115K,TQ on=4-5K,TQ off 2-3K, ECD=9.73,flow out 70%, WOB 2-10K, RPM=60,650 gpm @1200 psi. 12:00 18:00 6.00 2,802 3,241 INTRM1 DRILL DDRL P Drill from 2802'MD to 3241'MD, 3126'TVD,ART=1.33,AST=2.97, ADT=4.3,Jars=43.98, Bit=6.48, P/U=130k, S/0=105k, ROT=117k, Tq on/off=5/4k, ECD=9.62, Flow out=72%,WOB=3-5k,60 rpm, 700 gpm @1375 psi. Page 8 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,241 3,695 INTRM1 DRILL DDRL P Drill from 3241' MD to 3695' MD, 3430'TVD,ART=1.82,AST=2.56, ADT=4.38, Jars=48.36, Bit=10.86, P/U=132k, S/O=101k, ROT=118k, Tq on/off=9/6k, ECD=9.88, Flow out=72%, WOB=10-17k, 70 rpm, 700 gpm ©1400 psi. SPR's @ 9.2 ppg, 3444'MD Pump#1-30 spm @ 180 psi, 40 spm @ 230 psi. Pump#2-30 spm @ 180 psi, 40 spm @ 240 psi. 12/08/2013 Directional drill ahead from 3695' MD to TD @ 4833' MD. CBU x 5 and BROOH performing MAD pass. 00:00 06:00 6.00 3,695 4,260 INTRM1 DRILL DDRL P Driling from 3695' MD to 4260' MD, TVD=3702',ART=3.09, AST= 1.14, ADT=4.23, Total jar hours= 51.58, Bit hours= 14.08, Pick up weight 135K, Slack off weight 105K, Rotary weight 118K, TQ on=8-10K, TQ off=4-10K, EDC=9.92, Flow out 73%, WOB= 15K, RPM =80, GPM =700, psi= 1625. 06:00 12:00 6.00 4,260 4,463 INTRM1 DRILL DDRL P Driling from 4260'MD to 4463'MD, TVD=3792',ART= .12,AST= 3.26,ADT=3.38, Total jar hours= 54.96, Bit hours= 17.46, Pick up • weight 128K, Slack off weight 107K, Rotary weight 118K, TO on 5-10=K, TQ off=3-6K, EDC=9.76, Flow out 71%, WOB= 15-20K, RPM =80, GPM=655, psi = 1500. SPR's @ MD=4279', TVD=3711', MW=9.4 ppg, Time 6:30 a.m. #1 30 SPM =210 psi, 40 SPM =230 psi #2 30 SPM = 180 psi, 40 SPM =240 psi 12:00 18:00 6.00 4,463 4,833 INTRM1 DRILL DDRL P Drill from 4463' MD to 4833' MD, 3813'TVD.ART=1.68,AST=2.93, ADT=4.61,Jar Hrs=59.57, Bit Hrs=22.07, P/U=121k, S/O=98k, ROT=110k, Tq on/off=8/5k, ECD=10.14 ppg EMW, Flow out=78%,WOB=20-30k, 70 rpm, 700 gpm @ 1650 psi. 18:00 18:30 0.50 4,833 4,833 INTRM1 DRILL CIRC P Ream stand, survey on bottom, obtain SPR's @ 4833' MD, 3813' TVD MW 9.4+ppg. #1 30 spm @ 220 psi,40 spm @ 270 psi. #2 30 spm @ 220 psi,40 spm @ 280 psi. 18:30 21:45 3.25 4,833 4,833 INTRM1 CASING CIRC P CBU X 5 @ 700 gpm, 1500 psi. 70 rpm, 3-7k Tq, Monitor well static. Page 9 of 34 Time Logs Date From To Dur S. Depth'E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 4,833 4,467 INTRM1 CASING SRVY P PJSM-BROOH performing MAD pass from 4833'MD to 4467'MD @ 650 gpm, 1300 psi,70 rpm, 3-7k Tq, P/U=120k, S/0=105k. Calc Fill 3 bbl,2.75 bbl. 12/09/2013 Finish MAD pass,short trip to TD, POOH on elevators, LID BHA, Change out and test 9 5/8"rams, R/U and run 9 5/8"casing. 00:00 05:00 5.00 4,467 3,300 INTRM1 CASING SRVY P PJSM BROOH, MAD pass from 4467' MD to 3300'MD @ 650 gpm, 1300 psi, 70 rpm,TQ=5K,Act Fill= 53.83 bbl, Calc Fill= 19.5 bbl 05:00 06:15 1.25 3,300 2,459 INTRM1 CASING REAM P BROOH from 3300'MD to 2459'MD @ 650 psi, 1300 psi,80 RPM,TQ= 5-8K 06:15 07:30 1.25 2,459 2,459 INTRM1 CASING CIRC P Circulate hole clean @ 655 GPM, 1140 psi, 66%flow, 80 RPM, TQ= 3K(Blow down T.D.) 07:30 08:30 1.00 2,459 4,745 INTRM1 CASING TRIP P PJSM RIH from 2459'MD to 4745' MD Act disp= 18.7 bbl, Calc disp= 19.5 bbl 08:30 08:45 0.25 4,745 4,833 INTRM1 CASING WASH P Wash and ream from 4745'MD to 4833' MD©650 GPM, 1400 psi, 72%flow, 80 RPM, TQ=4-5K 08:45 10:15 1.50 4,833 4,743 INTRM1 CASING CIRC P Ciculate hole clean @ 700 gpm, 1500 psi, 72%flow, 80 rpm,TQ= 5K, P/U=125K, 5/0=103K, rack back one stand from 4833'MD to 4743' MD 10:15 10:45 0.50 4,743 4,743 INTRM1 CASING OWFF P Obtain SPR's, Blow down T.D. and monitor well(Static) SPR's @ 4743'MD, 3808'TVD, MW =9.6 ppg, Time 10:20am #1 30 SPM=200 psi,40 SPM=240 psi #2 30 SPM=210 psi,40 SPM =260 psi 10:45 12:00 1.25 4,743 3,912 INTRMI CASING TRIP P POOH on elevators from 4743'MD to 3912' MD 12:00 12:30 0.50 3,912 2,428 INTRM1 CASING TRIP P PJSM, Cont POOH from 3912'MD to 2428' MD. 12:30 12:45 0.25 2,428 2,428 INTRMI CASING OWFF P Monitor well @ casing shoe. (STATIC) 12:45 13:15 0.50 2,428 760 INTRM1 CASING TRIP P Cont POOH to 760'MD. 13:15 13:30 0.25 760 760 INTRM1 CASING OWFF P Monitor well @ HWDP. (STATIC) 13:30 13:45 0.25 760 206 INTRM1 CASING TRIP P Cont POOH racking back 5 stands of HWDP. 13:45 14:00 0.25 206 206 INTRM1 CASING SFTY P PJSM-Handling Nuke Sources. 14:00 14:45 0.75 206 109 INTRM1 CASING PULD P Rack back 1 std HWDP, L/D 3 flex collars. 14:45 15:15 0.50 109 109 INTRMI CASING PULD P Remove Nuke sources. 15:15 16:30 1.25 109 0 INTRM1 CASING PULD P PJSM, Cont L/D BHA, L/D MWD, drain motor, break bit.Total calc fill= 50.56 bbls,total act fill=59.50 bbls Page 10 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:00 1.50 0 0 INTRM1 CASING RURD P Clean&clear rig floor, L/D BHA tools down beaver slide, pull wear ring, set test plug. 18:00 19:15 1.25 0 0 INTRM1 CASING RURD P PJSM, C/O upper rams to 9-5/8". 19:15 20:30 1.25 0 0 INTRM1 CASING BOPE P PJSM, R/U and test upper rams to 250 low/3500 high,test annular to 250 low/2500 high for 5 minutes each,test w 9-5/8"test joint, R/D test eget. 20:30 22:30 2.00 0 0 INTRM1 CASING RURD P PJSM, R/U Casing eqpt. 22:30 00:00 1.50 0 124 INTRM1 CASING RNCS P PJSM, Run first 4 jts 9-5/8"casing per detail, making up float equipment and 1 joint. Check floats(Good) 12/10/2013 Land 9 5/8"casing, circulate hole clean,cement casing in place. Flush and freeze oprotect OA, BOPE test 4"and 5". 00:00 02:45 2.75 124 2,450 INTRMI CASING RNCS P PJSM run 9.625"CSG from 124'MD to 2450'MD. (59 Centralizers) 02:45 03:30 0.75 2,450 2,450 INTRM1 CASING CIRC P Circulate CSG volume @ 5 BPM, 300 psi,48%flow 03:30 04:45 1.25 2,450 3,833 INTRMI CASING RNCS P Continue to run 9.625 CSG from 2450'MD to 3833' MD 04:45 06:00 1.25 3,833 3,833 INTRMI CASING CIRC P Circulate bottoms up @ 5 BPM, 320 psi, 50%flow, pick up weight 158K, slack off weight 125K, (No losses) 06:00 07:00 1.00 3,833 4,823 INTRM1 CASING RNCS P Continue to run 9.625 CSG from 3833' MD to 4823' MD 07:00 07:45 0.75 4,823 4,823 INTRM1 CASING RURD P Make up landing joint with hanger, land hanger @ 4823'MD, Lay down franks fill up tool, blow down T.D., rig _ up cement head and load plugs. 07:45 10:45 3.00 4,823 4,823 INTRMI CEMEN'CMNT P Circulate and condition mud, stagging pumps up from 4 BPM,to 7 F BPM,450 psi,60%flow, FCP=400 psi, pick up weight 175K, slack off weight 110K, SIMOPS and PJSM on cement job. 10:45 12:00 1.25 4,823 4,823 INTRMI CEMEN-CMNT P Pump 5 bbls of water,test lines to 500 psi low, to 4000 psi high, pump 40 bbls CW100,40 10.5 ppg mud push II,drop bottom plug, pump 60 bbls 15.8 ppg lead slurry. 12:00 14:00 2.00 4,823 0 INTRMI CEMEN-CMNT P PJSM, Cont cement per program, displace w/rig pumps,topplu9 bumped at 3433 strokes, FCP 650 psi, pressure up to 1150 psi, hold for 5 minutes, Bleed pressure, check floats(GOOD), CIP @ 14:00. 14:00 15:30 1.50 0 0 INTRM1 CEMEN-RURD P PJSM, R/D casing and cement eqpt. L/D landing joint. 15:30 18:00 2.50 0 0 INTRM1 CEMEN-RURD P PJSM, Clean and Clear casing tools from rig floor, C/O bales and elevators, set&test packoff. Test to 5000 psi for 10 min(GOOD). 18:00 19:00 1.00 0 0 INTRM1 CEMEN-RURD P PJSM, C/O Upper rams to 3.5"x 6" VBR. Page 11 of 34 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:00 21:30 2.50 0 0 INTRM1 CEMEN-FRZP P PJSM, Perform injectivity test and annulus flush, ICP @ 10 bpm =540 psi, FCP @ 2.5 bpm=700 psi, pump 165 bbls H2O. 21:30 00:00 2.50 0 0 INTRM1 CEMEN-BOPE P PJSM,Test LRS lines to 2500 psi in 500 psi incriments(Test good), Freeze protect OA w/135 bbls of diesel, ICP= 1100 psi, FCP= 1200 psi. SIMOPS: Test upper rams w/5" test joint;test lower 2-7/8"x 5", Upper VBR and 4"dart valve and floor valve with 4"test joint,tested to 250 psi low, 3500 psi high,test annular to 250 low and 2500 high w/ 4"test joint for 5 minutes each. 12/11/2013 Drill out shoe track and 20'of new hole. CBU and FIT 12.5 ppg EMW, POOH, L/D BHA. LID 5"DP, P/U 4" DP, P/U BHA, RIH. 00:00 01:00 1.00 0 0 INTRMI CEMEN-RURD P PJSM, R/D test eqpt. P/U wear bushing, 8-3/4"bit and bit breaker. Install 10.50"wear bushing and change roughneck heads over to 5". 01:00 02:15 1.25 0 657 INTRM1 CEMEN-PULD P PJSM, M/U BHA#3 as per SLB Rep. 02:15 04:00 1.75 657 4,645 INTRM1 CEMEN-TRIPP RIH from 657' MD,tagging up at 4710'MD. POOH from 4710'MD to 4645' MD. P/U wt= 110k, S/O wt= 86k.Act disp=42.3 bbls, Calc disp =45.85 bbls. 04:00 04:45 0.75 4,645 4,645 INTRM1 CEMEN-CIRC P CBU @ 575 gpm,2000 psi, 65% flow. Blow down top drive. 04:45 05:30 0.75 4,645 4,645 INTRM1 CEMEN-PRTS P R/U to test casing to 3000 psi for 30 min as per Co Rep(GOOD). R/D test eqpt. 05:30 06:45 1.25 4,645 4,645 INTRM1 CEMEN SLPC P PJSM, Slip&Cut drilling line, 52'(8 wraps) 06:45 07:15 0.50 4,645 4,645 INTRM1 CEMEN-SVRG P Service rig. 07:15 09:00 1.75 4,645 4,833 INTRM1 CEMEN DRLG P Drill out shoe track and rat hole @ 500 gpm, 1610 psi,65%flow, 80 rpm,TQ=5-10k 09:00 09:15 0.25 4,833 4,853 INTRM1 CEMEN-DRLG P Drill 20'of new hole from 4833'MD to 4853' MD @ 500 gpm, 1610 psi, 65%flow, 80 rpm,TQ=5-7k, P/U wt = 110k, S/O wt=86k, Rot wt 105k. 09:15 09:45 0.50 4,853 4,853 INTRM1 CEMEN CIRC P CBU @ 500 gpm, 1650 psi, 65% flow, 80 rpm,TQ=5-7k 09:45 10:00 0.25 4,853 4,822 INTRMI CEMEN-TRIPP POOH from 4853'MD to 4822'MD. Blow down T.D. 10:00 10:15 0.25 4,822 4,822 INTRM1 CEMEN RURD P R/U test eqpt, perform FIT as per Co Rep. (EMW 12.5 ppg) 10:15 10:30 0.25 4,822 4,822 PROD1 DRILL CIRC P Obtain SPR's,test SLB drilllink system. 10:30 10:45 0.25 4,822 4,822 PROD1 DRILL OWFF P R/D test eqpt, blow down and monitor well(STATIC) Page 12 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:00 1.25 4,822 3,899 PROD1 DRILL TRIP P PJSM, POOH from 4822'MD to 3899'MD.Act fill=8.75 bbls, Calc _ fill=7.8 bbls. 12:00 13:00 1.00 3,899 655 PROD1 DRILL TRIP P PJSM, Cont POOH from 3899'MD to 655'MD. 13:00 13:15 0.25 655 655 PROD1 DRILL OWFF P PJSM, L/D BHA. SIMOPS: Monitor well 15 min(STATIC) 13:15 14:30 1.25 655 0 PROD1 DRILL PULD P UD HWDP,Jars,Collars, Stabiliaer &bit. Cal fill=47.41 bbls,Act fill= 49.20 bbls 14:30 14:45 0.25 0 0 PROD1 DRILL RURD P Clean&Clear rig floor. SIMOPS: take on 9.2 ppg OBM. 14:45 17:30 2.75 0 0 PROD1 DRILL RURD P PJSM, C/O Saver sub to XT-39, Space out grabbers, C/O Bell guide. 17:30 21:30 4.00 0 0 PROD1 DRILL PULD P PJSM, L/D 141 joints 5"DP via mousehole. 21:30 22:45 1.25 0 0 PROD1 DRILL RURD P C/O Mousehole, unload pipshed, C/O handling tools to 4", 22:45 00:00 1.25 0 0 PROD1 DRILL PULD PJSM-P/U 18 JTS 4"DP via mousehole 12/12/2013 Make up BHA, RIH w/4"DP to 4853'MD. Drill ahead f/4853'MD to 5365'MD TVD 3807'. Daily footage 508', ADT=3.11 hrs. 00:00 06:30 6.50 0 0 PROD1 DRILL PULD P PJSM P/U 4"Xt-39 and rack back in derrick(total 88 stands) 06:30 06:45 0.25 0 0 PROD1 DRILL RURD P Clean and clear rig floor 06:45 07:15 0.50 0 0 PROD1 DRILL PULD P Mobilize BHA tools to rig floor and steam off 07:15 09:15 2.00 0 377 PROD1 DRILL PULD P PJSM make up BHA#4 as per Schlumberger rep. 09:15 10:00 0.75 377 1,039 PROD1 DRILL TRIP P Single in hole w/4"XT-39 from 377' MD to 1039'MD 10:00 10:30 0.50 1,039 1,039 PROD1 DRILL DHEQ P Test MWD as per Schlumberger rep. @ 250GPM, 1300 psi, 56%flow, (Blow down T.D.) 10:30 12:00 1.50 1,039 2,272 PROD1 DRILL TRIP P Continue to single in hole W/4" XT-39 from 1039'MD to 2272'MD, Filling every 20 stands. 12:00 14:30 2.50 2,272 4,853 PROD1 DRILL TRIP P PJSM, Cont SIH from 2272'MD to 4637' MD, P/U stand 46-47, Ream to bottom w/stand 48,tag @ 4853' MD.250 gpm, 1550 psi,TQ 3k, RPM 80, P/U =98k, S/O=71k, ROT= 85k, Fill pipe @ 2272', 3800', Calc= 29.35 bbls,Act=32.9 bbls. 14:30 16:30 2.00 4,853 4,853 PROD1 DRILL CIRC P PJSM, Displace to 9.2 ppg OBM @ 250 gpm,l ICP= 1550 psi, FCP= 1900 psi, 80 rpm, TQ=2k. 16:30 16:45 0.25 4,853 4,853 PROD1 DRILL OWFF P Monitor well(Slight flow to static over 20 minutes) 16:45 17:00 0.25 4,853 4,853 PROD1 DRILL CIRC P Obtain SPR's @ 4830'MD, TVD _ 3813',9.2 ppg MW @ 17:00 hours. 17:00 17:45 0.75 4,853 4,853 PROD1 DRILL CIRC P Change Shaker screens, obtain clean hole ECD's. 17:45 19:00 1.25 4,853 4,853 PROD1 DRILL CIRC T Trouble shoot communications system, SLB MWD communications went down in the shack. Page 13 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 4,853 5,365 PROD1 DRILL DDRL P Drill ahead f/4853'MD to 5365'MD, TVD 3807'.ADT=3.11,Jar Hours= 3.11, Bit Hours=3.11. P/U=90K, S/O=80K, ROT=86K,Tq on=3K, Tq off=2K. ECD=9.65 ppg EMW, Flow out=45%,WOB=2-5K, RPM= 140, Pump @ 250 GPM= 1900 PSI. 12/13/2013 Drill ahead f/5365'MD to7356'MD TVD 3808'. Daily footage1991',ADT= 15.97 hrs. 00:00 06:00 6.00 5,365 5,946 PROD1 DRILL DDRL P Drill ahead f/5365'MD to 5946'MD, TVD 3810'.ADT=4.25, Jar Hours= 7.36, Bit Hours=7.36. P/U=93K, S/O=76K, ROT=88K,Tq on=3K, Tq off=2K. ECD=9.59 ppg EMW, Flow out=45%,WOB=3-4K, RPM= 150, Pump @ 250 GPM= 1980 PSI. 06:00 12:00 6.00 5,946 6,526 PROD1 DRILL DDRL P Drill ahead f/5946'MD to 6526'MD, TVD 3801'.ADT=3.68, Jar Hours= 11.04, Bit Hours= 11.04. P/U=94K, S/O=73K, ROT=87K, Tq on=3-4K, Tq off=3K. ECD=9.74 ppg EMW, Flow out=46%,WOB=3-4K, RPM= 150, Pump @ 250 GPM=2020 PSI. SPR's MD=6147', TVD=3836', MW =9.2 ppg,time: 08:17 #1 20 spm=340 psi, 30 spm=580 psi #2 20 spm=340 psi, 30 spm =670 psi 12:00 18:00 6.00 6,526 6,889 PROD1 DRILL DDRL P Drill ahead f/6526'MD to 6889'MD, TVD 3793'.ADT=3.53,Jar Hours= 14.57, Bit Hours= 14.57. P/U=98K, S/0=68K, ROT=85K,Tq on=3.5K, Tq off=3K. ECD=9.59 ppg EMW, Flow out=46%,WOB= 1-3K, RPM= 150, Pump @ 253 GPM=2075 PSI. 18:00 00:00 6.00 6,889 7,356 PROD1 DRILL DDRL P Drill ahead f/6899'MD to 7356'MD, TVD 3809'.ADT=4.51,Jar Hours= 19.08, Bit Hours= 19.08. P/U=96K, S/O=69K, ROT=85K,Tq on=3.5K, Tq off=3K. ECD=9.81 ppg EMW, Flow out=46%,WOB= 1-3K, RPM= 150, Pump @ 256 GPM=2175 PSI. Obtain SPR's @ 7830'MD, TVD 3809',9.2 ppg MW @ 23:55 Hrs. 12/14/2013 Drill ahead f/7356'MD to 9545'MD TVD 3808'. Daily footage 2189',ADT= 15.75 hrs. 00:00 06:00 6.00 7,356 7,962 PROD1 DRILL DDRL P Drill ahead f/7356'MD to 7962'MD, TVD 3812'.ADT=4.47, Jar Hours= 23.55, Bit Hours=23.55. P/U= 100K, S/O=68K, ROT=85K, Tq on=4K, Tq off=3K. ECD=9.98 ppg EMW, Flow out=45%,WOB=4K, RPM= 150, Pump @ 250 GPM=2100 PSI. Page 14 of 34 r - - Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 7,962 8,420 PROD1 DRILL DDRL P Drill ahead f/7962'MD to 8420'MD, TVD 3813'.ADT=2.97,Jar Hours= 26.52, Bit Hours=26.52. P/U= 100K, S/O=66K, ROT=86K,Tq on=4K, Tq off=3K. ECD=9.98 ppg EMW, Flow out=46%,WOB=2-5K, RPM= 150, Pump @ 250 GPM=2250 PSI. SPR's MD=8041',TVD=3812', MW =9.2 ppg,time: 07:13 #1 20 spm=430 psi,30 spm=740 psi #2 20 spm=430 psi,30 spm=770 psi 12:00 18:00 6.00 8,420 8,988 PROD1 DRILL DDRL P Drill ahead f/8420'MD to 8988'MD, TVD 3814'.ADT=4.57,Jar Hours= 31.09, Bit Hours=31.09. P/U= 110K, S/O=63K, ROT=85K, Tq on=4.5K, Tq off=3.5K. ECD=10.04 ppg EMW, Flow out=45%,WOB=3-7K, RPM= 150, Pump @ 250 GPM=2400 PSI. 18:00 00:00 6.00 8,988 9,545 PROD1 DRILL DDRL P Drill ahead f/8988'MD to 9545'MD, TVD 3808'.ADT=3.74, Jar Hours= 34.83, Bit Hours=34.83. P/U= 103K, S/O=63K, ROT=84K,Tq on=4.5K, Tq off=3.5K. ECD= 10.08 ppg EMW, Flow out=46%,WOB=2-4K, RPM= 150, Pump @ 258 GPM=2450 PSI. SPR's MD=9178',TVD=3809', MW =9.2 ppg,time: 19:45 #1 20 spm=450 psi, 30 spm=730 psi #2 20 spm=440 psi, 30 spm=740 psi 12/15/2013 Drill ahead f/9545'MD to 11147' MD TVD 3807'. Daily footage 1602',ADT= 16.37 hrs. Drilled through concretion 11123'MD-11125'MD from 17:30-22:30. 00:00 06:00 6.00 9,545 10,189 PROD1 DRILL DDRL P Drill ahead f/9545'MD to 10189' MD, TVD 3811'.ADT=4.56,Jar Hours= 39.39, Bit Hours=39.39. P/U= 103K, S/0=61K, ROT=88K,Tq on=5K, Tq off=4K. ECD= 10.22 ppg EMW, Flow out=47%,WOB=3-4K, RPM= 150, Pump @ 260 GPM=2520 PSI. 06:00 12:00 6.00 10,189 10,638 PROD1 DRILL DDRL P Drill ahead f/10189'MD to 10638' MD, TVD 3814'.ADT=3.63, Jar Hours=43.02, Bit Hours=43.02. P/U= 108K, S/O= 108K, ROT=87K, Tq on=5K,Tq off=5K. ECD= 10.18 ppg EMW, Flow out=46%,WOB= 2-3K, RPM= 150, Pump @ 262 GPM=2375 PSI. SPR's MD=10505',TVD=3814', MW=9.2 ppg,time: 09:50 #1 20 spm=420 psi,30 spm=710 psi #2 20 spm=430 psi,30 spm=690 psi Page 15 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 10,638 11,073 PROD1 DRILL DDRL P Drill ahead f/10638' MD to 11073' MD, TVD 3810'.ADT=3.97, Jar Hours=46.99, Bit Hours=46.99. P/U= 110K, S/O=56K, ROT=86K, Tq on=5K,Tq off=4.5K. ECD= 10.21 ppg EMW, Flow out=46%, WOB=2-5K, RPM= 150, Pump @ 266 GPM=2500 PSI. 18:00 00:00 6.00 11,073 11,147 PROD1 DRILL DDRL P Drill ahead f/11073'MD to 11147' MD,TVD 3807'.ADT=4.21,Jar Hours=51.20, Bit Hours=51.20. P/U= 110K, S/O=56K, ROT=86K, Tq on=5K,Tq off=4.5K. ECD= 10.21 ppg EMW, Flow out=46%, WOB= 12K, RPM= 150, Pump @ 264 GPM=2475 PSI. (@17:30- 22:30, Drilled through concretion from 11123'MD-11125' MD) SPR's MD=11147',TVD=3807', MW=9.2 ppg,time:23:15 #1 20 spm=440 psi,30 spm=740 i psi #2 20 spm=440 psi,30 spm=710 psi 12/16/2013 Drill ahead f/11,147'MD to 12,118'MD, 3,804'TVD. Daily footage 971',ADT 17.0= hrs. 00:00 06:00 6.00 11,147 11,450 PROD1 DRILL DDRL P Drill ahead f/11147'MD to 11450' MD,TVD 3806'.ADT=4.74, Jar Hours=55.94, Bit Hours=55.94. P/U= 110K, S/O=56K, ROT=86K, Tq on=5K,Tq off=4.5K. ECD= 10.27 ppg EMW, Flow out=46%, WOB=2-5K, RPM= 150, Pump @ 266 GPM=2500 PSI. 06:00 12:00 6.00 11,450 11,734 PROD1 DRILL DDRL P Drill ahead f/11450'MD to 11734' MD,ND 3804'.ADT=3.42, Jar Hours=59.36, Bit Hours=59.36. P/U= 112K, S/O=55K, ROT=87K, Tq on=5K,Tq off=5K. ECD= 10.28 ppg EMW, Flow out=48%,WOB= 1-3K, RPM= 150, Pump @ 262 GPM=2475 PSI. SPR's MD=11640',TVD=3804', MW=9.2 ppg,time: 10:00 #1 20 spm=500 psi, 30 spm =770 psi #2 20 spm=500 psi, 30 spm =780 psi 12:00 18:00 6.00 11,734 12,017 PROD1 DRILL DDRL P Drill ahead f/11734' MD to 12017' MD, TVD 3804'.ADT=3.98, Jar Hours=63.34, Bit Hours=63.34. P/U= 116K, S/O=50K, ROT=84K, Tq on=5.5K, Tq off=5K. ECD= 10.26 ppg EMW, Flow out=47%, WOB= 1-3K, RPM= 150, Pump @ 266 GPM=2690 PSI. Page 16 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 12,017 12,118 PROD1 DRILL DDRL P Drill ahead f/12,017'MD to 12,118' MD,TVD 3804'.ADT=4.86,Jar Hours=68.20, Bit Hours=68.20. P/U= 116K, 5/0=50K, ROT=86K, Tq on=6.5K,Tq off=5K. ECD= 10.19 ppg EMW, Flow out=47%, WOB=3-5K, RPM= 150, Pump @ 266 GPM=2,500 PSI. SPRs @12,112'md, 3,803'tvd, MW 9.2 ppg,23:30 hrs #1 20 SPM=470 psi 30 SPM=770 psi #2 20 SPM=470 psi 30 SPM=750 psi 12/17/2013 Drill to TD at 12,564' md, 3,816'tvd. Daily footage:446'.ADT=7.56 hrs. Circ btms up 3x, BROOH to inside 9-5/8"shoe. Pump sweep, open Circ sub and circulate at high pump rate. 00:00 06:00 6.00 12,118 12,396 PROD1 DRILL DDRL P Drill ahead f/12,118'MD to 12,396' MD,TVD 3816'.ADT=5.41,Jar Hours=73.61, Bit Hours=73.61. P/U= 122K, S/0=OK, ROT=85K, Tq on=6.0K, Tq off=6.0K. ECD= 10.27 ppg EMW, Flow out=47%,WOB= 1-4K, RPM= 150, Pump @ 262 GPM=2,500 PSI. 06:00 09:00 3.00 12,396 12,564 PROD1 DRILL DDRL P Drill ahead f/12,396'MD to 12,564' MD, TVD 3819'.ADT=2.15,Jar Hours=75.76, Bit Hours=75.76. P/U= 125K,S/0=43K, ROT=88K, Tq on=6.0K,Tq off=5.5K. ECD= 10.27 ppg EMW, Flow out=47%, WOB=3-5K, RPM= 150, Pump @ 262 GPM=2,500 PSI. Fire drill at 0700 hrs-crew response time=98 sec 09:00 09:30 0.50 12,564 12,564 PROD1 CASING CIRC P Zero directional tool,turn off MWD, obtain survey data.Take Slow pump rates. SPRs, MD-12,564 md,TVD= 3,819', MW=9.2 ppg, Time:09:15 hrs #1 20 SPM=510 psi, 30 SPM=840 psi #2 20 SPM=480 psi, 30 SPM=800 psi 09:30 12:00 2.50 12,564 12,564 PROD1 CASING CIRC P Circ bottoms up 3x at 270 gpm, 2,700 psi,48%flowline, 150 rpm,6K ft-lb TQ. Page 17 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 12,564 12,493 PROD1 CASING CIRC P PJSM. Continue 3x CBU racking back 1 stand/bttms up. Circ at 270 gpm,2,700 psi,48%flowline, 150 rpm and 6K TQ. SPRs, MD-12,493'md, TVD= 3,819' MW=9.2 ppg Time= 13:30 hrs #1-20 SPM=470 psi 30 SPM=740 psi #2-30 SPM=510 psi 30 SPM=780 psi 13:30 14:15 0.75 12,493 12,493 PROD1 CASING OWFF P Blow down Top Drive. Monitor well for 30 min.-ok 14:15 22:30 8.25 12,493 4,823 PROD1 CASING REAM P Backream from 12,493 to the 9-5/8" casing shoe at 4,823'. Pump at 270 gpm, 1,900 psi,46%flowline, 150 rpm, and 6K ft-lb TQ. Calc displacement=43.2 bbl,Actual displacement=76.73 bbl(33.5 bbl loss while BROOH)-Note ran centrifuge during BROOH 22:30 22:45 0.25 12,493 4,818 PROD1 CASING CIRC P POOH to inside the 9-5/8"casing at 4,818'md. Rack back one stand. Drop opening ball for the Well Cmdr circulating sub. Pump down at 2 bbl/min with 310 psi. Ball seated. Pressure up to 1,300 psi and held for 30 sec to activate tool. Increase pressure by 500 psi. At 1,750 psi Circ sub opened and pressure dropped back to 300 psi. 22:45 00:00 1.25 12,493 4,818 PROD1 CASING CIRC P Rotate pipe at 50 rpm while reciprocating and pumping weighted Hi-vis sweep at 450 gal/min and 1,550 psi. Saw 300%increase in cuttings returns just prior to bottoms up. Increased flow rate to 540 gpm max after sweep returned with cuttings volume approximately the same as while BROOH. PU=87K, SO=80K, ROT=85K,TQ=3K. (Note:After 3x btms up,dropped closing ball and closed Well Cmdr circ sub-ok) 12/18/2013 Continue to circ at high rate inside 9-5/8"casing shoe. Pump 3X btttoms up at 450-542 bbl/min. Drop closing ball and close Circ sub. RIH to TD. Circ btms up and wait on delivery of Solids Free MOBM. RU Vac trucks and lines. Hold Safety Shut down with both crews. PJSM for displacement. Pump 100 bbls spacer fluid and displace the well to SFMOBM,with 630 bbls. Page 18 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 4,818 4,818 PROD1 CASING CIRC P Continue circ at 542 gpm.2,010 psi, 65%flowline while rotating at 50 rpm,with cuttings volume approximately the same as while BROOH. Final circulating press= 2,000 psi. 00:15 00:30 0.25 4,818 4,818 PROD1 CASING CIRC P Shut down pumps, un-screw TD and drop closing ball. Pump at 2 bbl/min and 300 psi. Ball seated and pumped until pressure was1,300 psi. Shut down pumps and held for 30 sec to activate tool closing. Pressure up to 1,700 psi and pressure dropped to 275 psi indicating the closing of the Circ sub and all flow was going thru the BHA. Shut down pumping and blow down TD. 00:30 02:00 1.50 4,818 4,818 PROD1 CASING SVRG P PJSM. Slip and cut drill line(8 wraps,52'). Service rig 02:00 05:45 3.75 4,818 12,496 PROD1 CASING TRIP P PJSM for RIH. RIH from 4,818'to 12,496'md, filling pipe ever 20 stands. Calculated displacement= 43.74 bbl,Actual=36.57 bbl. 05:45 06:00 0.25 12,496 12,564 PROD1 CASING WASH P Wash and ream from 12,496'to 12,564'and at 260 gal/min,2,520 psi, 150 rpm, 6K ft-lb of TQ PU=85K, SO=45-50K, ROT=80K. 06:00 09:00 3.00 12,564 12,564 PROD1 CASING CIRC P Circ btms up 3X at 270 gal/min,49% flowline, 150 rpm,TQ=6K. 09:00 12:00 3.00 12,564 12,564 PROD1 CASING CIRC T Continue circ btms up 3X at 270 gal/min,49%flowline, 150 rpm, TQ=6K. Wait on trucks to arrive at location with Solids Free MOBM. Stand back one stand per hour. 12:00 19:30 7.50 12,564 12,564 PROD1 CASING CIRC T Continue circ btms up 3X at 270 gal/min,2,500 psi,49%flowline, 150 rpm,TQ=6K. Wait on trucks to arrive at location with Solids Free MOBM. Stand back 1/hr. 19:30 20:00 0.50 12,564 12,564 PROD1 CASING CIRC T Continue circ btms up 3X at 270 gal/min,49%flowline, 100 rpm, TQ=6K. Wait on trucks to arrive at location with Solids Free MOBM. Stand back 1/hr. 20:00 20:45 0.75 12,564 12,564 PROD1 CASING CIRC T Continue circ btms up 3X at 250 gal/min, 2,300 psi,49%flowline, 80 rpm, TQ=6K. Wait on trucks to arrive at location with Solids Free MOBM. Stand back 1/hr. Note: reduced RPM at request of MWD hand due to downhole vibration. 20:45 21:45 1.00 12,564 12,564 PROD1 CASING CIRC P Continue circ btms up 3X at 250 gal/min, 2,300 psi,49%flowline,80 rpm, TQ=6K. Spot 2 SFMOBM trucks and RU, spot 2 trucks for hauling returns and RU for displacement. Page 19 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 12,564 12,564 PROD1 CASING SFTY P Continue circ btms up 3X at 250 gal/min,2,300 psi,49%flowline,80 rpm, TQ=6K. Left minimum crew on the rig and mobilized both crews to rig camp and had a CPAI Safety Shut-down meeting. Crew change for truck drivers and rig crew. Held PJSM for displacing well to SFMOBM. 12/19/2013 Finish displacing well to SFMOBM. Flow chk-ok. POOH on elevators to inside 9-5/8"casing shoe. Drop ball and open Circ sub. Pump 3X btms up. Drop ball, close Circ sub and POOH. Handle BHA. Change out TD Saver sub, Upper pipe rams to 2-7/8"x 5"variables. RU to test BOPE. PJSM. 00:00 00:30 0.50 12,564 12,564 PROD1 CASING SFTY P PJSM with new Tour crew about displacing to SFMOBM. 00:30 03:00 2.50 12,564 12,564 PROD1 CASING CIRC P Pump 100 bbl of Hi-Vis weighted (10.6 ppg)sweep at 5 bbl/min, 1,775 psi,46%flowline, 150 rpm, TQ=6K. Displace 9.2 MOBM with 9.2 Solids free MOBM(45%-oil, 55%CaCl2 brine), pumping at 6 bbl/min, 2,500 psi,47%flowline, 150 rpm,TQ=6K. Monitored ECDs throughout and did not have to slow the pump rate. Calculated open hole volume=633 bbls, pumped volume=808 bbls. Did not see SFMOBM returns at surface. (Malin=9.2, MWout=9.5). Shut down pumps and continue reciprocating.Wait on truck in transit with backup load. PU= 115K, SO=45K, ROT=86K (during displacement) 03:00 06:30 3.50 12,564 12,493 PROD1 CASING CIRC P Blow down TD.Wait on additional SFMOBM delivery. Continue to work pipe without pumping,while rotating at 20 rpm and 5K ft-lb of TQ. Stand back one stand of DP. PU= 108K, SO=81K, ROT=86K (pumps off) 06:30 06:45 0.25 12,493 12,493 PROD1 CASING CIRC P Continue to displace 9.2 MOBM with 9.2 Solids free MOBM, pumping at 6 bbl/min,2,400 psi, 50%flowline, 20 rpm, TQ=5K. Calculated open hole volume=632 bbls, pumped volume=828 bbls total and had SFMOBM at surface. Pumped 65 bbl additional to cleanup. Page 20 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 12,493 12,493 PROD1 CASING CIRC P Obtain SPRs and blow down TD. SPRs: MD=12,564, TVD=3,821', MW 9.2 Time: 0655 MP1 20 SPM=430 psi, 30 SPM= 720 psi MP2 20 SPM= 440 psi, 30 SPM= 750 psi 07:00 07:30 0.50 12,493 12,493 PROD1 CASING OWFF P Monitor well. Slight flow out of drilipipe. Mud weight out of balance. 07:30 08:15 0.75 12,493 12,493 PROD1 CASING CIRC P Circulate to balance mud in DP and annulus at 6 bbl/min,2,400 psi, 50% flowline. Blow down TD. 08:15 08:45 0.50 12,493 12,493 PROD1 CASING OWFF P Monitor well. Static 08:45 10:00 1.25 12,564 10,600 PROD1 CASING TRIP P POOH on elevators from 12,493'to 10,600'md. Calculated fill= 10.8 bbl, Actual= 14.62 bbl. 10:00 11:15 1.25 12,564 10,600 PROD1 CASING SVRG P Change out air boot on Riser and service TD. 11:15 12:00 0.75 12,564 10,129 PROD1 CASING TRIP P POOH on elevators from 10,600'to 10,129'md. 12:00 14:30 2.50 10,129 4,823 PROD1 CASING TRIP P PJSM. POOH on elevators from 10,600'to 4,823'md. Held Spill Drill: CRT=85 sec 14:30 14:45 0.25 4,823 4,823 PROD1 CASING CIRC P Drop ball pump down at 2 bpm. Ball seated, pressure up to 1,300 psi, hold 30 sec, pressure up and tool opened at 1,750 psi. Bled pressure, tool open. 14:45 16:30 1.75 4,823 4,823 PROD1 CASING CIRC P CBU 3X at 500 gpm, 1,750 psi, reciprocating pipe and rotating at 30 rpm. Drop closing ball, pump down at 2 bpm and cycle tool closed. 16:30 16:45 0.25 4,823 4,823 PROD1 CASING OWFF P Blow down TD, flow chk-ok. 16:45 18:15 1.50 4,823 400 PROD1 CASING TRIP P Continue to POOH on elevators from 10,129' to BHA at 400'md. 18:15 18:30 0.25 400 400 PROD1 CASING TRIP P Monitor well at last joint of DP. _ Static. 18:30 20:00 1.50 400 0 PROD1 CASING PULD P PJSM. LD BHA. Note: Found a loose jet nozzle inside the bit that was from the PowerDrive. 20:00 20:45 0.75 0 0 PROD1 CASING OTHR P LD BHA,clean and clear rig floor. 20:45 22:30 1.75 0 0 PROD1 CASING BOPE P PJSM. Change out UPRs to 2-7/8"x 5"variable bore rams. Change our Saver sub from 4"XT-39 to 4.5"IF. 22:30 23:30 1.00 0 0 PROD1 CASING BOPE P Transfer SFMOBM to wash stack with. PU stack washer and wash down stack. 23:30 00:00 0.50 0 0 PROD1 CASING BOPE P RD stack washer and blow down TD. Page 21 of 34 Time Logs Date From To Dur S. Depth E DepthPhase Code Subcode -T Comment 12/20/2013 24 hr summary RU and test BOPE to 250/3,500 psi-all ok. Test Annular preventer to 250/2,500 psi-ok. Test Koomey unit with full pressure attained after 196 sec.Test witnessed by Chuck Scheve of the AOGCC. RD test equipment, RU and lay down all 4" DP. RU and run 5"HWDP. RIH to 4,583'md. Pump Deep Clean pipe cleaner to 4,583', reverse out with 9.2 ppg SFMOBM. Flow-chk, POOH installing Super-Sliders. 00:00 02:00 2.00 0 0 PROD1 CASING BOPE P PJSM. Pull Wear Bushing. RU test equipment. 02:00 08:00 6.00 0 0 PROD1 CASING BOPE P PJSM,Test BOPE to 250 PSI low/ 3500 PSI high for 5 minutes each with 5",4-Y2'and 2-6"test joints. Test#1: UPRs, manifold valves 1,12,13 and 14 and Manual Kill. Test #2: Upper IBOP, HCR kill, CV 9 and 3. Test#3: Lower IBOP, CV 5,8 and 10. Test#4: Dart valve, CV 4,6 and 7. Test#5: Floor valve and CV 2. Test#6: HCR choke and 4"kill line Demco valve. Test#7: Manual Choke valve, HCR Kill.Test#8: Annular preventer to 250/2,500 psi low/high. Test#9: LPRs.#10: Blind rams to 250/3,500 psi. Tested Koomey Unit: System pressure at 3,000 psi. Pressure after closing 1,700 psi. Pressure built back 200 psi in 47 sec, and full system pressure in 196 sec. Nitrogen bottles average pressure= 2,000 psi. Tested gas alarms, PVT alarms, Super choke and Manual choke. All tests were good. Testing witnessed by Chuck Scheve of the AOGCC. 08:00 08:45 0.75 0 0 PROD1 CASING BOPE P RD test equipment, blow down TD, choke, choke manifold and Kill line. Install 12-1/2"WB. 08:45 09:15 0.50 0 0 PROD1 CASING PULD P PU and set Mouse hole, change to 4"elevators,dress Iron Roughneck for 4" DP. Bring thread protectors to rig floor to thaw out. Held Spill Drill: CRT= 150 sec 09:15 12:00 2.75 0 0 PROD1 CASING PULD P PJSM. LD 4",XT-39 DP via the Mouse hole. 12:00 18:15 6.25 0 0 PROD1 CASING PULD P PJSM. Continue to LD 426 joints of 4",XT-39 DP via the Mouse hole. 18:15 19:00 0.75 0 0 PROD1 CASING PULD P LD Mouse hole, clean and clear rig floor. 19:00 19:30 0.50 0 0 PROD1 CASING SVRG P Lubricate the rig and service the Iron Roughneck. Page 22 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 00:00 4.50 10 3,877 PROD1 CASING PULD P PJSM. Change elevators. Make up mule shoe, PU 5"HWDP. Make/Break first 15 stands to break in new connections. Continue to single in hole to 3,877'md. PU= 175K, S0= 176K. Calc displacement=70 bbls,Actual= 64.94 bbl. 12/21/2013 Finish POOH and installing Super-sliders. Unload screens from boxes and load shed. RU casing running equipment. PJSM, run 4-%2', 107 micron, Ultra Fine screens. 00:00 01:00 1.00 3,877 4,850 PROD1 CASING PULD P PU 5"HWDP. Continue to single in hole to 3,877'-4,850'md. PU= 201K, SO= 175K. Calc displacement= 13.4 bbls,Actual= 12.3 bbl. 01:00 02:30 1.50 4,850 4,850 PROD1 CASING RURD P RU circulating equipment. Prep HWDP Deep Clean pickling fluid, in the pits. Monitor well. 02:30 04:00 1.50 4,850 4,850 PROD1 CASING CIRC P PJSM. Displace inside of 5" HWDP with 5 bbl of viscosified 9.2 brine, 10 bbl of Deep Clean,5 bbl of viscofied brine and 23.7 bbl of 9.2 ppg brine. Pump at 1 bbl/min, 125 psi. 04:00 04:45 0.75 4,850 4,850 PROD1 CASING CIRC P Reverse circulate pickle out of HWDP at 3 bbl/min, 290 psi,to rock washer. Blow down circulating lines. 04:45 07:00 2.25 4,850 4,850 PROD1 CASING CIRC P RU, screw into TD and CBU 5X with 120 rpm,TQ=6K, 9 bbl/min and 1,500 psi. 07:00 07:30 0.50 4,850 4,850 PROD1 CASING OWFF P Take SPRs, blow down TD. Monitor well-static. SPRs 4,580'md, MW=9.2+ MP1: 30 SPM=210 psi, 40 SPM= 290 psi MP2: 30 SPM=210 psi, 40 SPM= 290 psi 07:30 12:00 4.50 4,850 1,841 PROD1 CASING TRIP P POOH installing Super-sliders on every joint to 1,841'. PU=200K, SO= 177K. Calculated fill=50 bbl, Actual=50.2 bbl. 12:00 15:00 3.00 1,841 0 PROD1 CASING TRIP P Continue to POOH installing Super-sliders on every joint. Calculated fill=50 bbl, Actual=50.2 bbl. 15:00 15:30 0.50 0 0 PROD1 CASING OTHR P Clean and clear the rig floor. Fire Drill: CRT=85 sec 15:30 16:30 1.00 0 0 PROD1 CASING PULD P PJSM. PU casing tools to the rig floor. Remove screens from boxes in shed. Bring more boxes to the shed and remove screens. 16:30 18:30 2.00 0 0 PROD1 CASING PULD P PJSM. RU casing tools. 18:30 21:00 2.50 0 0 PROD1 CASING PULD P Continue to load liner screens in the pipe shed. Page 23 of 34 Time Logs Date From To Dur S. Depth E Depth Phase Code - Subcode -T Comment 21:00 00:00 3.00 0 337 COMPZ CASING RUNL P PJSM, Run 4-W, 11.6 lb/ft, L-80, R3, Hyd 563 liner with BOT Excluder 2000, 107 micron, Ultra-Fine screens, OD=5.26"(154 jts)plus 8 swell packers plus 13 blank jts of 4-W, 11.6 lb/ft, L-80, R3, Hyd 563, all made up with 5,300 ft-lb of torque and monitored with Torque-Turn equipment. All joints run made up properly with MU torque=5,300 ft-lb. Made up with Jet Lube Steel-Guard applied sparingly. 12/22/2013 Finish running 4'/z'Liner/screen lower completion to 7,876'md. Had proper fill. RD 4'/z"running tool, RU 5'/z' elevators. MU 5'/z'x 4'/2"XO, run 2 Jts of 5'/2"casing. RD 5'/z'elevators. RU False rotary table, slips and elevators. Run 2-7/8"tubing inner-string. 00:00 05:30 5.50 337 2,977 COMPZ CASING RUNL P PJSM, Continue to run 4-W, 11.6 lb/ft, L-80, R3, Hyd 563 liner with BOT Excluder 2000, 107 micron, Ultra-Fine screens, OD=5.26" plus swell packers tracers and 13 blank jts of 4-1/2', 11.6 lb/ft, L-80, R3, Hyd 563,all made up with 5,300 ft-lb of torque and monitored with Torque-Turn equipment. All joints run made up properly with MU torque =5,300 ft-lb. Made up with Jet Lube Steel-Guard applied sparingly. 05:30 06:00 0.50 2,977 2,977 COMPZ CASING OTHR P Clear and clean rig floor of all used packing materials. 06:00 08:30 2.50 2,977 4,806 COMPZ CASING RUNL P PJSM, Continue to run 4-W, 11.6 lb/ft, L-80, R3, Hyd 563 liner to 4,806' md. PU=90K, S0=82K. Calc Fill=34.9 bbl, Actual=30.6 bbl 08:30 12:00 3.50 4,806 4,806 COMPZ CASING PUTB P PJSM. Unload remaining boxes of Excluder screens in the pipe shed (no stacking of screens in multiple rows allowed). 12:00 14:00 2.00 4,806 4,806 COMPZ CASING PUTB P Continue to load Excluder screens in the pipe shed. 14:00 18:30 4.50 4,806 7,869 COMPZ CASING RUNL P Continue to run 4-'/z', 11.6 lb/ft, L-80, R3, Hyd 563 liner to 7,869' md. PU= 104K, SO=67K. Calc Displ. =21.94 bbl, Actual= 20.68 bbl 18:30 19:45 1.25 7,869 7,909 COMPZ CASING RUNL P LD Double stacked tongs and RU standard tongs. PU/MU 2 stands of 5'/z', 15.5 Ib/ft, L-80, Hyd 563 casing. RIH 19:45 21:00 1.25 7,909 7,909 COMPZ CASING RUNL P PJSM. RD standard tongs, PU double stacked tongs, RU false rotary table for 2-7/8",6.5 lb/ft, Hyd 511 inner-string 21:00 22:00 1.00 7,909 7,909 COMPZ CASING RUNL P Clear and clean the rig floor and under the pipe skate Page 24 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 7,909 7,909 COMPZ CASING RUNL P Service rig and TD 22:30 22:45 0.25 7,909 7,909 COMPZ CASING RUNL P PU 2-7/8"elevators from slide and RU. 22:45 23:00 0.25 7,909 7,909 COMPZ CASING RUNL P PJSM for running 2-7/8"inner-string 23:00 00:00 1.00 7,909 7,969 COMPZ CASING RUNL P PU/MU BOT ball seat and slick stick and 2 jts of PU 2-7/8", 6.5 lb/ft, L-80, Hyd 511, R3 tubing.Tubing MU=800 ft-lb. 12/23/2013 Finish running 2-7/8"inner-string. MU hanger. Run liner/screens to TD. Displace well to 9.2 filtered brine and circulate. RU cementers for pumping acid wash. 00:00 06:00 6.00 7,909 7,969 COMPZ CASING RUNL P PU/MU Continue to run 2-7/8", 6.5 Ib/ft, L-80, Hyd 511, R3 inner-string to 6,527'md, MU=800 ft-lb. PU 54K, SO=50K 06:00 07:45 1.75 7,909 7,969 COMPZ CASING RUNL P PU/MU Continue to run 2-7/8", 6.5 lb/ft, L-80, Hyd 511, R3 inner-string from 6,527' to 7,815'md, MU=800 ft-lb. PU 54K, SO=49K 07:45 08:00 0.25 7,909 7,969 COMPZ CASING RUNL P Tag up on No-Go slick stinger at 7,434'md, PU=54K, SO=49K 08:00 10:00 2.00 7,909 7,969 COMPZ CASING RUNL P PJSM, LD 3 Jts, PU B1 setting tool, ran in jt#267, made up space out 2-7/8",6.5 lb/ft, L-80, Hyd 511 pups (3.23',5.59', 5.83')and space out inner-string 2.99'off of No-Go. 10:00 10:30 0.50 7,909 7,969 COMPZ CASING RUNL P PU 5%"x 9-5/8"Flex-Lok-ZXP liner hanger, set in the mouse hole, mixed and poured Pal-Mix in the ZXP and let set while spacing out bottom of ZXP-B1 with top of 2-7/8" inner-string, using 7.43', 9.15', 9.26' and 1.88'pups. 10:30 12:00 1.50 7,909 7,969 COMPZ RPEQP1RUNL P PU Seal Bore Extension/FLCV, install in Mouse hole, stab ZXP packer into SBE, MU 5.5" connection with power tongs, PU ZXP pkr and SBE out of Mouse hole, stab inner-string into stump and MU. PU inner-string and remove false rotary table, MU Seal Bore to 5.5" string. 12:00 12:30 0.50 7,909 8,031 COMPZ CASING RUNL P PJSM. RIH with Packer on 5"HWDP with one Super-slider per joint from 7,969'to 8,031'md. PU first stand, break circ and pump at 3 bpm and 850 psi. Inner-string-sealed. 12:30 16:45 4.25 8,031 12,515 COMPZ CASING RUNL P Continue to run 4"Liner x 5.26" screens and 2-7/8"inner-string (combined wt in air=24.5 lb/ft)on 5" HWDP. Fill pipe every 9 stands.at 150 gal/min and 1,150-60 psi. 10, 500': PU= 174K, S0= 115K 11,320': PU= 178K, S0= 120K 12,560': PU= 180K, S0= 128K Page 25 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 17:00 0.25 12,515 12,536 COMPZ CASING RUNL P PU 5"HWDP single out of shed, MU to TD, pump 25 bbl at 3 bbl/min, 1,100 psi. Flow check-okay 17:00 17:15 0.25 12,536 12,546 COMPZ CASING RUNL P RIH to 12,536'md. Unscrew from TD, 1.25"drop ball, PU 10', 5"HWDP pup, RIH to 12,546'md. PU=245K, SO= 133K Calc Displ=81.67 bbl, Actual= 77.23 bbl 17:15 18:00 0.75 12,536 12,546 COMPZ CASING RUNL P Screw in TD to pup joint. Pump ball down at 3 bbl/min, 1,100 psi. Slow pump to 2 bb/min and 890 psi. After 40 bbls pumped of 60 bbls slowed to 1 bbl/min and 800 psi. Saw pressure spike to 1,000 psi and hanger set. Shut down pump and bleed off. RU test pump to blow the ball seat. PU until weight broke over at PU=215K, SO= 175K, confirming hanger is set. 12/24/2013 Set liner on depth at 12546'MD,Top of ZXP 4614' MD. Displace to 9.2 ppg brine. Pump 1st stage 265 bbl 9% Formic acid, chase w/100 bbl 9.2,soak 6 hrs. R/U and start to pump second acid job. 00:00 00:30 0.50 12,546 12,546 COMPZ RPCOM HOSO P PJSM, Set liner hanger per Baker rep,confirm release P/U=215k, S.O=125k, Pressure up to 4600 psi to shear ball seat. 00:30 01:30 1.00 12,546 12,546 COMPZ RPCOM CIRC P Break circulation @ 1 bpm, 500 psi, reduce to.5 bpm, 260 psi. 01:30 02:00 0.50 12,546 12,546 COMPZ RPCOM SFTY P PJSM on displacing well over to 9.2 ppg brine. 02:00 04:00 2.00 12,546 12,546 COMPZ RPCOM RURD P R/U trucks and circ lines,test hard lines to tiger tank. 04:00 07:45 3.75 12,546 12,546 COMPZ RPCOM CIRC P Displace well over to 9.2 ppg brine with 3%KCI per MI plan. Pump 20 bbl LVT 200 spacer, 55 bbl ph buffered vis brine,45 bbl vis brine, followed by 830 bbl 9.2 ppg brine to clean up. 07:45 08:15 0.50 12,546 12,546 COMPZ RPCOM OWFF P Monitor well losses, 12 bph. L/D 10' pup joint, Blow down Top Drive. 08:15 12:00 3.75 12,546 12,546 COMPZ RPCOM RURD P R/U cement line and contingency HP hose to cellar,empty pits and rock washer. Spot and R/U SLB acid flush truck, R/U hard line in cellar. Clean trough in pits, clean out trip tank. Losses remain at 12 bph. 12:00 12:15 0.25 12,546 12,546 COMPZ RPCOM SFTY P PJSM on pumping the 9%Formic acid with SLB, DDI and MI. 12:15 12:30 0.25 12,546 12,546 COMPZ RPCOM PRTS P Flood and PT lines to 4000 psi. 12:30 14:45 2.25 12,546 12,546 COMPZ RPCOM STIM P Pump 265 bbl of 9%Formic acid in 9.2 ppg 3%KCI/NaCl brine, followed by 100 bbl filtered 9.2 ppg 3% KCI brine @ 5 bpm, 1250 psi. Total pumped 365 with 154.5 bbl returns. 210.5 bbl lost during acid job. Page 26 of 34 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 12,546 12,546 COMPZ RPCOM RURD P Blow down lines, monitor well, (Static losses 40 bph) 15:00 21:30 6.50 12,546 12,546 COMPZ RPCOM STIM P Allow Formic acid to soak 6 hrs per plan. Losses varied, averaging 48.5 _ bbl/hr.Total lost in 6 hours 291 bbl. 21:30 22:15 0.75 12,546 12,546 COMPZ RPCOM RURD P Spot acid trucks on location, hook up lines. 22:15 22:30 0.25 12,546 12,546 COMPZ RPCOM SFTY P PJSM with SLB, DDI and MI, Formic acid pumping. 22:30 23:15 0.75 12,546 12,546 COMPZ RPCOM RURD P Prime up SLB pumps, hook up vac trucks, PT lines. Check lines to tiger tank. 23:15 00:00 0.75 12,546 12,546 COMPZ RPCOM STIM P Start pumping, pumped 5 bbl brine to establish circulation @ 5 bpm, 1270 psi. Start pumping 9% Formic acid solution, 50 bbl away at 00:00. Total losses to formation for today=396 bbl. 12/25/2013 Complete 2nd stage acid job and soak,displace well to clean 9.2 ppg brine. Set ZXP packer and test. Shift RS seal assy, POOH laying down 5"HWDP. 00:00 01:00 1.00 12,546 12,546 COMPZ RPCOM STIM P Continue pumping 265 bbl 9% Formic Acid treatment, chase with 100 bbl 9.2 ppg 3%KCI/NaCl brine, 5 bpm @ 1350 psi,264 bbl, or 70% returns during pumping. 01:00 08:15 7.25 12,546 12,546 COMPZ RPCOM STIM P Blow down and R/D SLB pumping unit, cement lines and vac trucks. Monitor well via trip tank while acid _ soaks. Losses from 40-30 bph. 08:15 12:00 3.75 12,546 12,546 COMPZ RPCOM CIRC P PJSM and displace well to clean 9.2 ppg 3%KCI/NaCl brine. Pumped 6 bpm©2175 psi, 5500 stks then shut down and dicert returns to tiger tank due low ph 2.2. Pumped total of 1225 bbls with 800 bbl, or 65% returns. 12:00 13:15 1.25 12,546 12,546 COMPZ RPCOM OWFF P Monitor well until flowback stopped, well flowed back 86 bbl prior to going static,then return to loss. Adjusted Total lost to formation for tour=709 bbl Adjusted Cumulative loss= 1105 bbl 13:15 13:45 0.50 12,546 12,546 COMPZ RPCOM OWFF P Monitor well for 30 minutes 13:45 14:00 0.25 12,546 12,546 COMPZ RPCOM RURD P PJSM and R/D cement line 14:00 14:15 0.25 12,546 12,546 COMPZ RPCOM PACK P Set ZXP liner top packer @ 4614'MD per Baker rep and procedure. (P/U=217k, 5/O=125k) 14:15 14:45 0.50 12,546 12,546 COMPZ RPCOM PRTS P R/U test liner top packer to 1500 psi for 30 minutes on chart. Page 27 of 34 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 12,546 12,516 COMPZ RPCOM RURD P R/D test equipment, pull up to release RS seal assembly. No indication of release. P/U=208k, S/O=125k. R/U and pump 30 bbl @ 5 bpm, 1350 psi to clear seal assy. Shut down and B/D top drive. 15:00 23:00 8.00 12,516 7,940 COMPZ RPCOM TRIP P PJSM and POOH, laying down 5" HWDP to 7940'MD, removing Super Sliders. 23:00 00:00 1.00 7,940 7,940 COMPZ RPCOM RURD P PJSM, L/D Super Sliders, Clean and clear rig floor. Calc Fill=83.5,Actual Fill=265 bbl. P/U=55k, S/0=53k. Total loss to formation for tour=285 bbl Total loss to formation for day=994 bbl Cumulative loss to formation= 1390 bbl 12/26/2013 Complete POOH laying down 2-7/8"H511, close FLCV and spot inhibited brine. R/U and begin making up ESP BHA. 00:00 00:30 0.50 7,940 7,940 COMPZ RPCOM RURD P PJSM,continue clearing rig floor of 5"handling tools and SuperSliders. R/U double stack tongs, M/U safety valve. 00:30 01:45 1.25 7,940 7,820 COMPZ RPCOM PULD P PJSM, Lay down Baker liner running tools and pup joints. 01:45 07:30 5.75 7,820 4,699 COMPZ RPCOM TRIP P L/D 2-7/8"inner string to 4699'MD. Calc fill=7.4 bbl,Actual Fill=110.5 _bbl. 07:30 08:00 0.50 4,699 4,612 COMPZ RPCOM OWFF P Monitor loss rate at 4699'MD,31 bph. Lay down 3 joints pulling slick joint through FLCV to 4612' MD. P/U 50k. 08:00 08:30 0.50 4,612 4,612 COMPZ RPCOM OWFF P Monitor well for 30 minutes-Staitic. FLCV closed. 08:30 09:00 0.50 4,612 4,612 COMPZ RPCOM RURD P CIO elevators and rig up circulating equipment. 09:00 10:45 1.75 4,612 4,612 COMPZ RPCOM CIRC P PJSM and CBU at 5 bpm,610 psi. Pumped 300 bbl,followed by 45 bb19.2 ppg inhibited brine(2% CRW-132), chase with 27 bbl 9.2 straight brine. 10:45 11:45 1.00 4,612 4,612 COMPZ RPCOM RURD P Monitor well, Static. Rig down circulating equipment, C/O elevators, M/U safety valve. 11:45 12:00 0.25 4,612 4,582 COMPZ RPCOM TRIP P Continue POOH, laying down 2-7/8" H511 to 4582'MD. Total losses to the formation today 344 bbl Cumulative losses to formation 1734 bbl Page 28 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:45 4.75 4,582 0 COMPZ RPCOM TRIP P PJSM, continue POOH laying down 2-7/8" H511 to surface, lay down slick joint. Calc Fill=10.5 bbl,Actual Fill=10.5 bbl 16:45 18:15 1.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor 18:15 19:15 1.00 0 0 COMPZ RPCOM SLPC P PJSM, Cut and Slip 65'drilling line. 19:15 19:45 0.50 0 0 COMPZ RPCOM SVRG P Service rig 19:45 20:15 0.50 0 0 COMPZ RPCOM RURD P R/U, pull wear bushing, LID running tool. 20:15 00:00 3.75 0 0 COMPZ RPCOM RURD P Load pipe shed with ESP equipment, R/U tools to run upper completion. Verify lengths on ALC equip, R/U sheaves for ESP cables,spooler unit. R/U tubing handling tools. M/U safety valve. 12/27/2013 Made up seal assembly, 11jts tubing and ALC BHA to 525'MD. Performed cable splice and test cable. M/U gauge carrier, splice guage cables and test. Start in hole, parted gauge cable,waiting on splice. 00:00 01:45 1.75 0 0 COMPZ RPCOM PULD P Make up ALC BHA and rack back in derrick. (Profile nipple, PxP tubing jt, pump can assy, 3 Motor shrouds, reducer and pup). 01:45 03:30 1.75 0 0 COMPZ RPCOM RURD P P/U tools to rig floor, prep jewelry in pipe shed,double/triple check running order and mark joints for placement. 03:30 04:15 0.75 0 310 COMPZ RPCOM RCST P M/U seal assembly and locator, tubing to 310' MD. Discover hydraulic leak in mezzanine, powering rig floor hydraulics. Shut down to repair. 04:15 06:00 1.75 310 310 COMPZ RPCOM RGRP T Welder repair pinhole in hydraulic line @ mezzanine level. 06:00 08:30 2.50 310 525 COMPZ RPCOM RCST P Continue running tubing, landing nipple,CMD sliding sleeve(in open position verified)ALC BHA to 525' MD. 08:30 11:00 2.50 525 525 COMPZ RPCOM ALFT P Connect power cable to wet connect on pump can assembly. 11:00 12:00 1.00 525 525 COMPZ RPCOM ALFT P PJSM, R/U ESP Sheave and cable to rig floor. R/U Control line and sheave on off driller side rig floor. 12:00 17:30 5.50 525 525 COMPZ RPCOM ALFT P Slpice ESP cable,secure same. 17:30 18:00 0.50 525 525 COMPZ RPCOM ALFT P Test ESP cable splice, passed. 18:00 22:45 4.75 525 525 COMPZ RPCOM ALFT P Make up guage carrier,splice wires to carrier and test. Seal and secure same with SS band and cannon clamp. 22:45 23:15 0.50 525 525 COMPZ RPCOM ALFT P Test guage wire continuity, passed. Page 29 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 525 532 COMPZ RPCOM ALFT T Begin RIH with completion string to pick up GLM, RIH 8', Gauge wire conduit spooler locked up and parted the SS conduit and wire at the spooler. Operator at spooler didn't notice it was pulling tight. Conduit appears more fragile(thinner)than regular control line. 12/28/2013 RIH with completion to 1475' MD. R/U Slickline to set Rigless ESP motor, isolation sleeve and tubing stop. Troubleshoot and redress motor deployment shear pins,sucessfully set motor after several attempts. 00:00 02:30 2.50 532 532 COMPZ RPCOM ALFT T PJSM,wait on splice kit, Splice damaged gauge control line,test continuity OK. 02:30 05:00 2.50 532 1,475 COMPZ RPCOM RCST P Continue RIH with GL Manderl w/ SOV and 4-1/2"tubing completion, ESP cable and gauage line to 1475' MD. S/O=50k. Calc Disp=3.14 bbl, Actual Disp=5.74 bbl. 05:00 08:30 3.50 1,475 1,481 COMPZ RPCOM ALFT P PJSM, install ESP motor in mouse hole, M/U 5.75' EUE B x IBT P XO, R/U wireline, perform continuity test on ESP cable and gauge wires-Good. 08:30 09:15 0.75 1,481 1,481 COMPZ RPCOM ALFT P M/U 3.80 drift on Slick line and RIH to 1009'MD no problems, POOH. 09:15 11:30 2.25 1,481 1,481 COMPZ RPCOM ALFT P PJSM,assemble and service motor for deployment. 11:30 12:45 1.25 1,481 1,481 COMPZ RPCOM ALFT T RIH w/motor on Slickline, attempt to plug in motor-Unsuccessful, POOH with motor assy. 12:45 14:15 1.50 1,481 1,481 COMPZ RPCOM ALFT T Re-dress motor shear pins, remove jars f/Slickline and add weight bars. Re-zero motor RKB. 14:15 15:15 1.00 1,481 1,481 COMPZ RPCOM ALFT T RIH with motor and new slickline assy.Attempt to plug in motor, unsuccessful. POOH with motor assy. 15:15 17:30 2.25 1,481 1,481 COMPZ RPCOM ALFT T Re-pin plug arm,test fire twice on rig floor,tool functioning properly, decision made to attempt run again. 17:30 19:00 1.50 1,481 1,481 COMPZ RPCOM ALFT T RIH w/motor and new slickline assy, attempt to shear pins, no overpull after 19 attempts, POOH with motor assy. 19:00 20:00 1.00 1,481 1,481 COMPZ RPCOM ALFT T On surface,observed pins misfire, re-pin with aluminum upper pins and brass lower pins. 20:00 21:15 1.25 1,481 1,481 COMPZ RPCOM ALFT P RIH with re-pinned assembly and deployed. Observed shear of pins @ 630 lbs overpull,slacked off and checked continuity. Plugged in, _ shear off GS, POOH with slickline. 21:15 22:00 0.75 1,481 1,481 COMPZ RPCOM ALFT P M/U isolation sleeve, re-dress shear pins and RIH with sleeve. Set same and POOH with slickline. 22:00 22:15 0.25 1,481 1,481 COMPZ RPCOM ALFT P M/U tubing stop run, re-dress shear pin, RIH and set same, POOH. Page 30 of 34 Time Logs Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 1,481 1,481 COMPZ RPCOM ALFT P PJSM, R/D slickline tools and equipment. Prep to continue RIH with tubing per detail. 12/29/2013 RIH with Rigless ESP/GL completion. M/U hanger and ESP connections. Land, RILDS,set TWC.Test IA and test to 1500 psi. Start bleeding down per schedule. 00:00 02:15 2.25 1,481 2,478 COMPZ RPCOM RCST P PJSM,continue RIH with completion from 1475'MD to 2478'MD. S/O=60k. 02:15 03:15 1.00 2,478 2,478 COMPZ RPCOM ALFT P Perform continuity test, PJSM-R/U slickline. 03:15 04:00 0.75 2,478 2,478 COMPZ RPCOM RURD P M/U wireline tools with 3.80"drift 04:00 05:00 1.00 2,478 2,478 COMPZ RPCOM SLKL P RIH with slickline 3.80"drift,tag at 1901' MD tubing stop, POOH. 05:00 05:30 0.50 2,478 2,478 COMPZ RPCOM RURD P R/D slickline equipment, store tools and BOP on floor. 05:30 08:00 2.50 2,478 3,486 COMPZ RPCOM RCST P Continue RIH to 3486' MD, 5/0=73k 08:00 08:30 0.50 3,486 3,486 COMPZ RPCOM RURD P PJSM, rig up slickline for drift run, peerform ESP cable and TEC wire tests. 08:30 09:30 1.00 3,486 3,486 COMPZ RPCOM SLKL P RIH with drift to 1100' MD, POOH, L/D slickline. 09:30 12:00 2.50 3,486 4,373 COMPZ RPCOM RCST P Continue RIH to 4373' MD, S/O=75k. Actual Disp=14 bbl, Calc Disp=13 bbl. 12:00 12:30 0.50 4,373 4,587 COMPZ RPCOM RCST P PJSM, continue RIH to jt 141,4587' MD.Perform ESP cable and TEC wire tests. 12:30 13:30 1.00 4,587 4,630 COMPZ RPCOM HOSO P Continue RIH to No-Go,tag top of SBR @ 4647'MD,tubing depth 4665' MD. Lay down 3 joints, P/U space out joints 7.84'and 2.08', P/U jt 142. RIH set slips, P/U=82k, 5/O=75k. Calc Disp=14.45 bbl,Actual _ Disp=16.15 bbl. 13:30 14:30 1.00 4,630 4,630 COMPZ RPCOM RURD P PJSM, R/U slickline, SIMOPS rig up slickline tools. 14:30 15:30 1.00 4,630 4,630 COMPZ RPCOM SLKL P RIH with 3.80 drift to 1500'MD. SIMOPS perform ESP cable and TEC wire tests. 15:30 16:00 0.50 4,630 4,630 COMPZ RPCOM RURD P PJSM, R/D slickline, L/D XO pup, remove slickline tools from rig floor. 16:00 18:30 2.50 4,630 4,630 COMPZ RPCOM HOSO P M/U hanger, cut and splice ESP cable.Terminate TEC cable @ hanger. 18:30 20:00 1.50 4,630 4,630 COMPZ RPCOM ALFT P Test ESP electrical connections,tie into hanger probe, re-test ESP cable @ the probe.Test TEC cable hanger void to 5000 psi for 5 min,test TEC cable. Secure both cables to upper tubing joint with 5 ea-SS bands. Total bands run in hole: 134-Cannon clamps, 13-SS Bands Page 31 of 34 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 4,630 4,660 COMPZ RPCOM HOSO P RIH and land hanger, RILDS.Test hanger void to 5000 psi for 15 minutes,witness by Co Rep. SIMOPS-R/D cable sheaves from derrick. Completion landed at 4659.9' MD, 5.4'off fully located. 21:30 22:45 1.25 4,660 4,660 COMPZ RPCOM MPSP P PJSM, Monitor well for 30 minutes- static, lay down landing joint. Set two way check. R/U and test to 1500 psi via IA. Chart test for 10 minutes. 22:45 00:00 1.25 4,660 4,660 COMPZ WHDBO PRTS P Bleed TWC/annulus test pressure after test per supplemental procedure. Bleed from 1500 psi to 750 psi at 50 psi per minute for 15 minutes,then hold for 30 minutes and resume. Bleed from 750 psi to 375 psi at same rate over 8 minutes. SIMOPS-R/D and send ALC and Centrilift tools and equipment down beaverslide. 12/30/2013 Bleed down well pressure, N/D BOP, N/U tree adapter and test. Fluid leaking through penetrator. Decision to pull and repair. N/U BOP and test prior to pulling hanger, IBOP and valve failures, commence replacement. 00:00 01:30 1.50 0 0 COMPZ WHDBO PRTS P Continue bleeding off well pressure per procedure to avoid ESP cable damage. SIMOPS-L/D ALC and centrilift equipment, casing equipment and cleaning pits. 01:30 02:00 0.50 0 0 COMPZ WHDBO PRTS P Blow down and rig down circ lines, blow down choke and kill lines. Clean out drip pan. 02:00 03:30 1.50 0 0 COMPZ WHDBO NUND P PJSM-N/D BOPE 03:30 04:30 1.00 0 0 COMPZ WHDBO RURD P Pull tree into cellar, prep wellhead. 04:30 06:00 1.50 0 0 COMPZ WHDBO SEQP P Prep adaptor flange, change out port seal, install SRL seal.ALC perform continuity tests on cables. 06:00 08:30 2.50 0 0 COMPZ WHDBO SEQP P N/U adaptor flange,test TEC line. Install mount and bracket for TEC line. 08:30 11:00 2.50 0 0 COMPZ WHDBO PRTS T Test adaptor flange, could not get test after bleeding off several times. Checked IA and observed hydraulic oil leaking through indicating a leaking penetrator. 11:00 12:00 1.00 0 0 COMPZ WHDBO RURD T Call town engineer before proceeding. Clear rig floor, lay down subs and tools. 12:00 12:15 0.25 0 0 COMPZ WHDBO RURD T Continue waiting on orders, decision made to N/D adaptor flange and N/U BOP,test and pull hanger to floor for repair. 12:15 13:30 1.25 0 0 COMPZ WHDBO NUND T PJSM and N/D adaptor flange, inspect and pack pentrator seal for BOP test. 13:30 15:15 1.75 0 0 COMPZ WHDBO NUND T PJSM and N/U BOPE Page 32 of 34 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:30 1.25 0 0 COMPZ WHDBO RURD T PJSM and R/U to test BOPE 16:30 22:00 5.50 0 0 COMPZ WHDBO BOPE T Test all BOPE with 4-1/2"test joint 250/5000 psi 5 min.#1-Test annular 250/2500.#2-Upper VBR 2-7/8"x5", Upper IBOP, HCR Kill,Valve 9,11. #3-Valve 5,8,10.#4-Dart Valve, Valve 4,6,7.#5-Floor valve, valve 2,12.#6-Valve 1. Accumulator test: System pressure 2975 psi, pressure after closing 1700 psi,200 psi attained-45 sec, Full pressure attained-192 sec. N2 5 bottle average 1975 psi. AOGCC Bob Noble waived witness of test. 2 failures, Demco valve and lower IBOP, beginning repair for retest. 22:00 22:30 0.50 0 0 COMPZ WHDBO RURD T Rig down test equipment, blow down choke manifold and choke/kill lines. 22:30 00:00 1.50 0 0 COMPZ WHDBO RGRP T PJSM and C/O Lower IBOP 12/31/2013 Complete BOP test. Pull hanger to floor, C/O penetrator seals,splice I Wire and test. Re-land hanger,test and bleed down. N/D BOP, N/U adapter flange and test-Good. N/U tree,test, FP, RDMO 00:00 02:00 2.00 0 0 COMPZ WHDBO BOPE T Continue changing out lower IBOP and 4-1/2"saver sub 02:00 02:30 0.50 0 COMPZ WHDBO RURD T R/U BOP test equipment. 02:30 03:30 1.00 0 COMPZ WHDBO BOPE T Test#1-Upper IBOP, break between Upper and lower IBOP,4"Demco kill line valve.#2-Lower IBOP, HCR kill, break between lower IBOP and saver sub. 03:30 04:00 0.50 0 COMPZ WHDBO RURD T R/D test equipment, blow down top drive and kill line. 04:00 04:30 0.50 0 COMPZ WHDBO MPSP T Suck out stack, Pull TWC. 04:30 05:15 0.75 4,660 COMPZ WHDBO OWFF T M/U landing joint, monitor well for 30 minutes. SIMOPS, swap to generator power, off highline @ 08:30. 05:15 06:15 1.00 4,660 4,625 COMPZ WHDBO RCST T BOLDS, Pull hanger to rig floor P/U=85k, monitor well via trip tank. 06:15 08:15 2.00 4,625 4,625 COMPZ WHDBO ALFT T Splice TEC wire, C/0 seals on penetrators and reassemble. One penetrator appeared to not be fully seated. 08:15 09:00 0.75 4,625 4,625 COMPZ WHDBO ALFT T C/O hanger seals on hanger, connect ESP cable to penetrator. test hanger void and swagelock fittings to 5000 psi. 09:00 09:30 0.50 4,625 4,625 COMPZ WHDBO ALFT T Perform electrical integrity tests on cables and TEC wire, all check good. 09:30 10:30 1.00 4,660 4,660 COMPZ WHDBO HOSO T Land hanger, S/O 76k,tubing landed @ 09:45 hrs, RILDS.Test hanger seals to 5000 psi 15 minutes witnessed. 10:30 11:00 0.50 0 0 COMPZ WHDBO OWFF T Monitor well static, UD landing joint, set TWC. Page 33 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 COMPZ WHDBO RURD T R/U circ lines, pressure up down IA, test tubing seals and TWC 1500 psi for 10 minutes. Start bleed down schedule. 12:00 15:30 3.50 0 0 COMPZ WHDBO OWFF T PJSM-Continue bleed down procedure. Monitor well for 30 minutes. 15:30 16:00 0.50 0 0 COMPZ WHDBO NUND T PJSM-N/D BOPE 16:00 16:15 0.25 0 0 COMPZ WHDBO ALFT T Test ESP cable and TEC cable- good. 16:15 18:30 2.25 0 0 COMPZ WHDBO NUND P PJSM-N/U adapter flange,tie in TEC cable©adapter flange.Test hanger void to 5000 psi for 15 min, witnessed by Co Rep(Good)Test ESP and TEC cables. Good 18:30 21:00 2.50 0 0 COMPZ WHDBO NUND P PJSM-N/U tree and test to 5000 psi for 10 minutes charted, R/D test equipment. 21:00 21:15 0.25 0 0 COMPZ WHDBO MPSP P PJSM and pull TWC per Cameron rep. 21:15 22:45 1.50 0 0 COMPZ WHDBO RURD P R/U Little Red Services for freeze protect, SIMOPS R/U Scaffolding in cellar. 22:45 00:00 1.25 0 0 COMPZ WHDBO FRZP P PJSM, Freeze protect well via Little Red Services with 150 bbl diesel. PT surface lines to 2500 psi, start pumping diesel @ 2 bpm, 30 psi at tree,400 psi in unit. 01/01/2014 Complete freeze protect and open FLCV, perform final checks on ESP and gauge wires. Install BPV and actuator valves, secure well. Rig released @ 08:00. 00:00 00:45 0.75 0 0 COMPZ WHDBO FRZP P PJSM-Continue to pump freeze protect diesel, pumped 150 bbl @ ICP 2 bpm-450 psi, FCP 2 bpm-700 psi. Shut in pressure 350 psi. 00:45 02:00 1.25 0 0 COMPZ WHDBO FRZP P U-Tube well,ALC and Centrilift performed electrical integrity checks. 02:00 02:15 0.25 0 0 COMPZ WHDBO RURD P Shut in well, Blow down circ lines. 02:15 03:00 0.75 0 0 COMPZ WHDBO DHEQ P PJSM with LRS and rig crew. Rig up and PT line to 4000 psi. Open annulus and pressure up, open FLCV @ 2150 psi with tubing closed. FP on IA 100 psi. 03:00 03:30 0.50 0 0 COMPZ MOVE DHEQ P ALC and BHI performed final checks on ESP cables and TEC wire-Good. 03:30 05:15 1.75 0 0 COMPZ MOVE MPSP P Shut in well, rig down lines, R/U lubricator and test to 500 psi. Set type H BPV. 05:15 06:30 1.25 0 0 COMPZ MOVE SEQP P PJSM-Install actuator valve, rig down scaffolding, clean out cellar box. Secure well.Tubing=60 PSI, IA= 100 psi, OA=0 psi. 06:30 08:00 1.50 0 0 COMPZ MOVE DMOB P Prep cellar, blow down and prep for move. Rig released 0 08:00 hrs. Rig move on hold due truck off road 0 Y. Monitoring Phase II weather. II Page 34 of 34 G)01-1-0-1 cncnqco 3.-,107J mw -i o El.co m3 m g,N og occm om2 cmv 5 4 S D »»3. 7- » go . . m700 > 2 .< Vo cH aOa f y '000__N° n 0 a od eaA ON m W C N aIH eci O (� p (� j v W 0m 0 a N N W N Oar NA• S O-.-N W W y V{0)OI W JONo0D N 0 CD W N W W W W IAO a O N to(OcDNa mN W wCaw J A Nco W+ a ro((�TN OoA Nt0 W A+co W NwwfTNcop-+ww t0 V V wJ W A V+J O !p 3 ANv W W NNA W W Vw W A c D NNAN<O W I+NNAaJ V NN W Iwo 0.0N0 V N W WAV-+w0S?0 N O O Z Z Z N 0^c-� c�^^-)-)XX0.--n L �pV Im,V 0 V M a n cm 9 os j"D D O "' m c°N CO D W 0 0 ++DC F 71 N a. 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Z O m .tet N N N N N F 0 WM M rJ W V"NO a,r--co NO.-Mr r MN 000NCD W Nh. : tit i c- 15 P)j zr 51 z30 Regg, ,James B (DOA) From: Rig 141 [rig141@doyondrilling.comj 2¢ l' i Z47/13Sent: Monday, December 09, 2013 11:38 AM C i To: Regg, James B (DOA); n1334@conocophillips.com; Brooks, Phoebe L (DOA); tom.d.rawlins@conocophillips.com Cc: DOA AOGCC Prudhoe Bay; Herbert, Frederick 0 Subject: RE: Emailing: Doyon 141 BOP 12-6-2013.xls Mr. Regg I aborted that test between test 3 & 4 a needle valve on the test hose started leaking around the stem packing. Changed out the needle valve and continue with testing the Dart valve. v Original Message \� From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Monday, December 09, 2013 10:06 AM ( 'S To: Rig 141; n1334Pconocophillips.com; Brooks, Phoebe L (DOA); i `C a;1“Y 51 to tom.d.rawlinsOconocophillips.com 1-- Cc: DOA AOGCC Prudhoe Bay Subject: RE: Emailing: Doyon 141 BOP 12-6-2013.xls C'�cL(�J , - What is failed high pressure test (following successful low pressure 11 test) between tests 3 and 4? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Original Message From: Rig 141 [mailto:rig1410doyondrilling.com] Sent: Saturday, December 07, 2013 2:47 PM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); n13340conocophillips.com; Brooks, Phoebe L (DOA); tom.d.rawlinsPconocophillips.com Subject: RE: Emailing: Doyon 141 BOP 12-6-2013.xls Original Message From: Rig 141 Sent: Saturday, December 07, 2013 6:26 AM To: AOGCC; 'AOGCC' ; 'Jim Regg' ; 'n1334@conocophillips.com'; 'PBOEBE'; Tom D. Rawlins (tom.d.rawlinsPconocophillips.com) Subject: Emailing: Doyon 141 BOP 12-6-2013.xls Your message is ready to be sent with the following file or link attachments: Doyon 141 BOP 12-6-2013.xls Note: To protect against computer viruses, e-mail programs may prevent 1 sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq(a,alaska.gov AOGCC.Insriectorsna alaska.gov phoebe.brooksalaska.qov Contractor: Doyon Rig No.: 141 DATE: 12/6/13 Rig Rep.: John Piper Rig Phone: 670-4966 Rig Fax: 670-4990 Operator: Conoco Phillips Op. Phone: 670-4963 Op. Fax: 670-4983 Rep.: Larry Hill E-Mail n1334@conocophillips.com Well Name: 1C-151 PTD# 2131230 Operation: DrIg: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/2500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" P Pit Level Indicators P P #1 Rams 1 3 1/2"X 6" P Flow Indicator P P #2 Rams 1 BLINDS P Meth Gas Detector P P #3 Rams 1 2 7/8"X 5" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8"X 5K P Inside Reel valves 0 NA HCR Valves 2 3 1/8"X 5K P Kill Line Valves 2 3 1/8"X 5K P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1700 psi. P Quantity Test Result 200 psi Attained 56 sec P No. Valves 14 P Full Pressure Attained 219 sec P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 5 Btls. @ 2000 psi CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 4.5 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested with 5"test joint all test 250 Lo/3500 Hi. And choke valves. Tested the Annular to 250 Lo/2500 Hi. All test held fo 5 Mins. --re5-)-ate cAlciteof C. ---) 24 HOUR NOTICE GIVEN YES X NO Waived By Lou Grimaldi Date 12/4/13 Time 1:39 AM Witness Test start 07:00 AM Finish 11:30 AM Dnrm 1 rLd7d /Rnvienr1 !14/7!11 2\ rinvnrt 1.41 RCD 1)_n_)fl1 vie (A2u Ic-15( Regg, James B (DOA) 2-131z3u From: Rig 141 [rig141 @doyondrilling.com] Rei- ( 7) /�3 Sent: Saturday, December 07, 2013 2:47 PM l l To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); n1334 @conocophillips.com; Brooks, Phoebe L (DOA); tom.d.rawlins@conocophillips.com Subject: RE: Emailing: Doyon 141 BOP 12-6-2013.xls Attachments: Scan0454.pdf; BOP test chart 2 for 12-6-13.pdf; BOP test chart 1 for 12-6-13.pdf Original Message From: Rig 141 Sent: Saturday, December 07, 2013 6:26 AM To: AOGCC; 'AOGCC' ; 'Jim Regg' ; 'n1334@conocophillips.com'; 'PBOEBE'; Tom D. Rawlins (tom.d.rawlins@conocophillips.corn) Subject: Emailing: Doyon 141 BOP 12-6-2013.xls Your message is ready to be sent with the following file or link attachments: Doyon 141 BOP 12-6-2013.xls Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. __________:_1-:------- 15 M. �,�g��rte= ��- -- 4,411411 E,/ 30 '. OP""1W-_,01P-7i/N/W1.1.11.4PIONINI il 'rip 4%11.41*. ° .W•011.14.woossomowIll..... /417Zionewftwallan111.111:ft,ft.'"‘- 4 4/0 /4 , 9140 olooliiiiiiiiiiiiaraimm..._. ,;..,441 io. 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Doyon Rig 141 BOP Test Well # / Driller r Date t /6 , Close Open Open 1) Top pipe rams, valve 1, 12,13, choke valves 2,3,4,5,6,7, 14, & manual kill line valve 8,9, & 10 Open 4" Demco kill line valve. '2) Upper IBOP, HCR kill, valves choke valve 12 & 9 & 11 manual kill valve \3) Lower IBOP, valves 5,8, & 10 Upper IBOP valves 9,11 \4) Dart valve, valves 4,6, & 7 Lower IBOP valves 5,8, & 10 \5) Floor valve & valve 2 Dart valve & valve 7 \6) HCR choke, 4"Kill line Choke valve 1 & open Demco valve HCR kill "7) Manual choke valve HCR choke valve & 4" HCR kill Demco valve \8) Annular preventer Top Pipe Rams 9) Lower pipe rams Annular Preventer Accumulator test none Time pressure System pressure Pressure after closed 200psi Attained ic Full pressure attained :lc, Nitrogen bottles avg , 10) Blind rams, valve 3 manual choke, valves 1 & 2 tv.1 (r., OF/ � THE STATEI 1/iAlaska Gil and Gas '' ==ar. ' °ALASKA FCVaifiGit,i O1MtSSIiGItFi ~ *, GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA*E� Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1C-151 ConocoPhillips Alaska, Inc. Permit No: 213-123 Surface Location: 1313' FNL, 4366' FEL, SEC. 12, T11N, R10E, UM Bottomhole Location: 2458' FNL, 1374' FEL, SEC. 35, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to 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, Cathy P oerster Chair DATED this day of September, 2013. STATE OF ALASKA t., V m.m. AL .A OIL AND GAS CONSERVATION COMM!. iN AU 14 2013 PERMIT TO DRILL _ _ 20 MC 25.005 '. ,(j t la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ , Service- Winj ❑ Single Zone Q _ lc.Specify if well is proposed for: Drill ❑✓ ,Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket O Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 1C-151 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12541' , TVD: 3904' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1313'FNL 4366'FEL,Sec. 12 Twn 11N Rng 10E,UM - ADL025638/1' .4.1)1._02.5 ...,(-77 �� West Sak Oil Pool . ' Top of Productive Horizon: 8.Land Use Permit: sf':jG,(313.Approximate Spud Date: 4830'FNL 4726'FEL,Sec. 1 Twn 11N Rng 10E,UM 931695 10/25/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2458'FNL 1374'FEL,Sec.35 Twn 12N Rng 10E,UM 2560 AC. 1374' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:86.3 • feet 15.Distance to Nearest Well Open Surface: x-561919.4 •' y- 5968922.9 Zone-4 GL Elevation above MSL:58.3 ' feet to Same Pool: 1865' 16.Deviated wells: Kickoff depth: 250 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91.36 degrees Downhole: 1691 psi / Surface: 1261 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2455' 28' 28' 2455' • 2436' • 1370 sx ALC,280 sx DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 4945' 28' 28' 4945' • 3817' • 830 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 7596' 4745' 3805' 12541' 3904' Stand alone screens(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date if`127)/3 22. I hereby certify that the foregoing is true and correct. David Lee @ 263-3741 Contact david.l.lee(a�conocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager III Signature -(. Phone 265-6120 Date e((z>i 21 Commission Use Only Permit to Drill ,.., / API Number: Permit Approval �� See cover letter for other Number: i_ G Z� 50-02:(i" Z.3`f97- C� "CIL*: requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: / ,, p tr.s .,1_ , 0 3 5 .,c 10s ` Samples req'd: Yes ❑ No[+ Mud log req'd:Yes Non' (/ / H2S measures: Yes ❑ No Directional svy req'd:Yes 2' No❑ Spacing exception req'd: Yes ❑ No Inclination-only svy req'd:Yes❑ No Dr II � APPROVED BY / Approved by: P COMMISSIONER THE COMMISSION Date: cp - (� if fil V tirg4J/1 3 Submit Form and \/ Form 10-401(•evised 10/ 012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate �� • Conoco h�•ll�p s AUG 14 2013 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 David Lee Phone (907) 263-3741 August 12, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1C-151 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the West Sak"D"sand. The expected spud date for 1C-151 is, October 25th 2013. The West Sak in the 1C area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1C-151 well will be drilled down structure to the North with a planned lateral length of approximately 8000'. The lateral will cross three minor faults with throws anticipated between 5— 25'. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 8.3 ppg equivalent during the drilling of this well. A FIT test to a minimum of 12.0 ppg will be performed-after setting the surface casing and drilling out 20'of new formation, and a FIT test of 12.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1C-151. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely, David Lee Kuparuk Drilling Engineer A tion for Permit to Drill,Well 1C-151 • Revision No.0 Saved: 13-Aug-13 Permit It - West Sak Well #1C-151 . f.1 Application for Permit to Drill Document A Ma el Maximize Well %/glue Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AA C 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (Ml VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 1C-151 PERMIT.doc Page 1 of 7 Printed:13-Aug-13 P tion for Permit to Drill,Well 1C-151 Revision No.0 Saved: 13-Aug-13 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CerCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-151. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1313' FNL 4366' FEL Sec. 12 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 86.3'AMSL Northings 5,968,922.9 Eastings: 561,919.5 Pad Elevation 58.3'AMSL Location at Top of Productive Interval 4830'FNL 4726'FEL Sec. 1 Twn 11N Rng 10E UM (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4610' Northings: 5,970,682.2 Eastings:561,543.7 Total Vertical Depth, RKB: 3788' Total Vertical Depth, SS: 3702' Location at Total Depth 2458'FNL 1374' FEL Sec. 35 Twn 12N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12541' Northings: 5,978,318.06 Eastings: 559,548.2 Total Vertical Depth, RKB: 3904' Total Vertical Depth, 55: 3818' 1C-151 PERMIT.doc Page 2 of 7 f' Printed:13-Aug-13 • A tion for Permit to Drill,Well 1C-151 • Revision No.0 Saved: 13-Aug-13 and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1C-151 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036, or 20 AAC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-151. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1C area are 0.432 psi/ft, or 8.33 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,261 psi, calculated thusly: MPSP = (3,904 ft TVD)(0.432 - 0.11 psi/ft) = 1,261 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-151 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(1); 1C-151 will be completed with a 9-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1C-151 PERMIT.doc Page 3 of 7 Printed:13-Aug-13 A tion for Permit to Drill,Well 1C-151 Revision No.0 Saved: 13-Aug-13 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 40 94 K55 Welded 80 28/ 28 108/ 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 2455 28/ 28 , 2455/ 2436, 1370 sx ALC Lead, 280 sx DeepCRETE Tail Cement Top planned @ 2900' 9.625 12.25 40 L-80 Hydril 563 4945 28/ 28 . 4945/ 3817 MD/2844'TVD Cemented w/ 830 sx 15.8 ppg Class 4.5 6.75 11.6 L-80 Hydril 563 7596 4745/ 3805 12541 / 3904 , Screens—no cement • Screens 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-151 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1C-151 PERMIT doc Page 4 of 7 Printed:13-Aug-13 A tion for Permit to Drill,Well 1C-151 Revision No.0 Saved: 13-Aug-13 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Ml Gel Spud Mud) Spud to Base Base Permafrost to Permafrost Surface TD Value Value Density(ppg) 8.8 9.4 Funnel Viscosity 300 200 (seconds) Yield Point 40-80 40-80 (cP) PH 9.0 9.0 API Filtrate NC 8.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Lateral Mud Program (Ml FazePro OBM) Value 13 3/8"Csg Shoe to 9-5/8"Csg Point Density(ppg) 9.3—9.8 Value PV(cP) 20-30 Density(ppg) 9.2 - 9.6 / YP Fann 35 6 RPM (lb/100 ft2) 12 - 18 (lb/100 ft2) 10 - 12 Internal Phase API Filtrate CaCl2(%by 18 -25% (cc/30 min)) 6 weight) pH 9.5 — 10.0 Oil/Water Ratio 70/30 Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1C-151 PERMIT.doc Page 5 of 7 �, , Printed:13-Aug-13 A tion for Permit to Drill,Well 1C-151 • Revision No.0 Saved: 13-Aug-13 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34"insulated conductor to +/- 80'RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16"hole to casing point at +/- 2455' MD/ 2436'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13.375", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 12.25"bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 12.0ppg EMW, recording results. 8. Directionally drill to 9-5/8"casing point at 4945' MD/ 3817'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 9.625", 40# L80, Hydril 563 casing to surface. Top of cement to be 2900'MD/ 2844'TVD which corrresponds to 500'above the Ugnu C formation. 40% excess cement will be pumped to ensure coverage of the Ugnu C zone. 11. Install wellhead x 9.625" packoff and test to 3500 psi. 12. Flush 13.375"x 9.625"annulus with water, followed by diesel. 13. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 14. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 12.0ppg EMW, recording results. 1C-151 PERMIT.doc Page6of7 Printed:13-Aug-13 A tion for Permit to Drill,Well 1C-151 Revision No.0 Saved: 13-Aug-13 15. Directionally drill 6.75"hole to West Sak D Sand to TD at +/- 12541' MD/ 3904'TVD as per directional plan. 16. POOH to 9.625"shoe. TIH and perform final circulations. Pump out of Hole. 17. PU and run 4-1/2"screened liner. 18. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 19. Finish running liner to TD to land liner and set liner hanger @ +/-4745'MD/3805'ND, then displace well to Schlumberger acid through washpipe (9% formic acid for 1C-151). 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 4.5"tubing and outer ESP housing and RIH 1000'. 23. RIH with ESP (pump and motor) and land in outer housing using slick line. 24. Continue running in hole with 4.5"tubing. Land tubing. Set BPV 25. Nipple down BOPE, nipple up tree and test. Pull BPV. 26. Freeze protect well with diesel by pumping into 4.5"x 9.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 27. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1C Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1C Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1C-151 PERMIT.doc Page 7 of 7 Printed:13-Aug-13 1 C-151 grilling Hazards S_ _nmary 16" Open Hole / 13.375" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 12.25" Open Hole / 9.625" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low , Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub and cuttings bed impellers, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out or backreaming Attachment 2-1C-151 Drilling Hazards Summary.doc 8/12/20133:40:36 PM 1C-151 Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casin. V2 Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250%excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 1873.5' MD. Client:CPAI Revision Date: July 12,2013 Prepared by:Jenna Houston Location:Anchorage, AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -270 min. (pump time plus 120 min.) Mobile:(907)223-8916 ALC @ 11.02 ppg- 1.93 ft3/100 lb sk email:jhouston2@slb.com 0.9933 ft3/ft x 110 x 1.0 (no excess) = 110 ft3 < TOC at Surface 0.42059 ft3/ft x (1777-110) x 3.50 (250%excess) = 2454 ft3 0.42059 ft3/ft x (1873.5-1777) x 1.50 (50%excess) = 61 ft3 2454 ft3 + 61 ft3+ 110 ft3= 2625 ft3 2625 ft3/ 1.93 ft3/sk= 1361 sks(-1370 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE- 1.63 ft3/1001b sk 0.42059 ft3/ft x (2473.5-1873.5) x 1.50 (50%excess) = 379 ft3 0.84065 ft3/ft x 80' (Shoe Joint) = 68 ft3 379 ft3+ 68 ft3 = 447 ft3 447 ft3/ 1.63 ft3/sk = 275 sks 1 Round up to 280 sks BHST = 71 °F, Estimated BHCT = 75°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,777'MD(1,770 TVD) Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 6.0 40.0 6.7 6.7 MUDPUSH II 6.0 50.0 8.3 15.0 Pause 0.0 0.0 5.0 20.0 < Top of Tail at ALC Lead Slurry 6.0 467.3 77.9 97.9 1873.5'MD Surface Tail 5.0 79.4 15.9 113.8 DeepCRETE Slurry Pause 0.0 0.0 5.0 118.8 Fresh Water 5.0 10.0 2.0 120.8 Pause 0.0 0.0 5.0 125.8 Mud 8.0 338.4 42.3 168.1 Mud 3.0 10.0 3.3 171.4 < 13 3/8",68#casing MUD REMOVAL in 16"OH Expected Mud Properties:9.5 ppg, Pv<20, Ty< 20 TD at 2,473.5 MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv= 17-21, Ty=20-25 (2,430'TVD) Centralizers: As per CPAi program. • Mark of Schlumberger ORIGINAL 1C-151 Schlumberger CemCADE Preliminary Job Design 9 5/8" Intermediate V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: July 12,2013 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G + adds - 1.16 ft3/sk Mobile:(907)223-8916 email:jhouston2@slb.com 0.31321 ft3/ft x (5003'-2900') x 1.4 (40% excess) = 923 ft3 Shoe Volume: 0.42572 ft3/ft x 80'x 1.00 (no excess) = 34 ft3 Totals: 923 ft3+ 34 ft3= 957 ft3 957 ft3/ 1.16 ft3/sk= 825 sks(830 sks) BHST= 100 °F, Estimated BHCT= 72 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 40.0 8.0 8.0 13 3/8",68#casing MUDPUSH II 5.0 40.0 8.0 16.0 at 2473.5'MD Pause 0.0 0.0 5.0 21.0 Tail Slurry 5.0 170.3 34.1 55.1 Pause 0.0 0.0 5.0 60.1 Fresh Water 5.0 10.0 2.0 62.1 Pause 0.0 0.0 5.0 67.1 Top of Tail at Mud 6.0 353.3 58.9 126.0 end of pumping Mud 3.0 10.0 3.3 129.3 < 2900'MD MUD REMOVAL Recommended Mud Properties:9.5 ppg, Pv<20,Ty<20. As thin and light as 9 5/8",40# possible to aid in mud removal during cementing. in 12 1/4"hole Spacer Properties:10.5 ppg MudPUSH* II, Pv=25-30, Ty=30-40 Centralizers: As per CPAi program TD at-5003'MD (3802'TVD) * Mark of Schlumberger *- , / # I )[ §> �ƒ) ! • )\fs ] § m��® « ,k! 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A 0 0 0 0 0 O S O 0 0 0 0 0 O O 0 0 0 O p n O d O O O 0 0 3 y -1 -1 n -i H n H 0 H -1 n -i H n H a H - n - H v ca -I n - C M m m m m p_ m m m m 71 m m m m 71 -n mCo - 0 0 °� 0 0 4 O �, 0 0 a' 0 0 »' O �' 0 0 » O O N °' 0 :' O 0 C O J J - J 0 O CO 001 0 •0 00)) -4 -' 00) 01 0o 0) 6) Na 0 -, N v W 3 cr 01 (O co no J co CO Co (JO (JO N b v O V V W 00 N N N) O ° 0 O 3 M • • CD J 0 6) N (O J (0 J 01 j _, _, N A Cn W 00 W p m W V co CO W (A (J Cr) 00 0i in Co j O O p Na O) (0 A V C+) O N) (n 03 W A E E O W A K E E K a 0 m gCD-41 0 0 a a a a 0 a a a -{ r 00)) C 0 0 G O a 0- O C) OG S g. m xiN 0) N 0) O c (o' 0 3 a m0 fDm 0) Cr. cD 0 m 3 Z1 E co A 3 A O 3 R. a 0 mg -I -a - � g 3 m R m � p("o m 0 )3 -a 0 ++ C N N Q ^^O ^^C» n 0) lV'@ (n C fD QW) 60j WW C) =a -00O 00 3 (i) 3 3 0 n O A A O o � 0) • co c 1• Q N 0) (0 co N 3 . . 4, N O C CA o w — _ o? _ 3 C, CD 03a " fDv w CD m 0. w pp N- N N N 'D T. T� C7 M VO 9 7 j 'O 7 W co OD) N O _ 2 O CD W O CO V n n x U - W CO W CO - y o CD O m w CO a D O O CO V M A O J U) 0 N N N CW 0 O O O COO 7 p C C co co O CO "O A (0 — CO - CO - Cr Cn N V CA W V J •A W W J N N N N N N N N CO A CO (0 A V -, CA A O Ni CD CO CO Ni U) D D H (/) CO W CD o v v o v . a. a _ N p p -A Q Nn Cv 0) 0) - W A A -0 0 'G _, n- O A fl) �_ W m O O c N O O W O CD v o ` CD 0 N• C O 3 O v man mm7' y 73iii P, �Stm C) d co CO , c • m °�• 0 •• `•' n O `•R m 3 f o 0 3 mom - o K 5 m m= CD cri o • C C000D N 0, 3 CD a OC N N _ 2 /^coO y_ N @© CJl C CD 83S3 W W 0 O O Q r. (.07 7 0 n CO N - s W v v �� �a O) to C "• col Cn (0 - Sec MD Inc Azi TVD +N/ +E/-W DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 0.. 0.00 0.00 0.00 0.00 From MD- _ MD 3 550.31 4.50 330.00 550.00 10.22 -5.90 1.50 330.00 11 1 C-151 wp 15 ..00 40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 28.00 To 12541.21 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 170.00 103.30 6 2108.12 5.76 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 250 - 350 3650 - 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 350 - 450 4150 - 4650 9 4223.95 65.00 350.85 3673.77 1401.08 -297.50 0.00 0.00 1430.34 14:40,August 02 2013 10 4628.18 81,08 349.10 3791.30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Jul13 Heel 450 550 4650 - 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.26 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 G..OBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 T1 --_ --••••• 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 3878.72 '9th FlooDq�n To 52rveymull cool 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 2B.002WO.00 1F1516m15(Ran:1C-15141C( Flan 1C-151MWD wNcCAZ-SC 1250 1450 9150 10150 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 4628.182541.211C-151Wp15(Ra1:1C-151MWDdFR-WC-C/SSC 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 1450 - 1650 10150 - 12150 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 CASING DEraLs 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 TVD MD Name sae 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3.6.03 139/8'x 10- 13-378 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 3791.3828.195'8'x12-1/4.959 26 10913.43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0,17 8066.48 12541.21 01/2x50/4.4-1rz 2650 - 3150 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 T7 32 12050.52 7928 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 7928 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 T8 35 12313.50 8907 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 8907 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/ -1.1 -30/330 14040f4 30 -_ /o-II //j s!!ie _\ ■ 131 �ir��►� �f1=14 60/300 / // / fir�'i 470 tae®N.♦.k 6��oy �1�� � , �f/►�s1 / /// / / r p,•iii v/�ea._.ili►{�i� ,®a 41i� i p e/� �.��Ir'w �w-A71 / 1 1aiiL1®i .•�®�5 1r+���/I ail ,0e$41��,••rt j / i_iO��� 4 it �!►v1 7t`r `l, Th..f%Cit�...'.i%I� �`'�ry__'/' �. i AA / R,',ai i `®1®7� �®�,A►i A.ti 1Ri 0411,• 1`74i ConocoPhillips 1 C- 1 51 wp 15 Schlumberger Alaska ANTI-COLLISION SETTINGS 1441,August 022013 Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 12541.21 Results Limited By: Centre Distance: 1451.31 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 2050.00 1C-151wp15 (Plan: 1C-151) CB-GYRO-SS 2050.00 2446.03 1C-151wp15 (Plan: 1C-151) MWD+IFR-AK-CAZ-SC 2446.03 4628.18 1C-151wp15 (Plan: 1C-151) MWD+IFR-AK-CAZ-SC 4628.18 12541.21 1C-151wp15 (Plan: 1C-151) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2427.30 2446.03 13-3/8" x 16" 13-3/8 3791.30 4628.18 9-5/8" x 12-1/4" 9-5/8 12541.21 4-1/2"x 6-3/4" 4-1/2 o a M I 77-7 0 Wde.) a C 300- lj II Q 0 ( I,, , 150- - - 0 J� I . t 0) i v �I 1 , ,' Ip���IIN `�� 0 i i i i I i I I i I I 1 I I i i I I i I I I I i i 1 I i 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND -e- 1C-05,1C-05,1C-05 V2 -I- 1C-11,1C-11,1C-11 VO Q 1C-172,1C-172AL2PB2,1C-172AL2PB2 VO -9- 1C-06,1C-06,1C-06 V2 $ 1c-11,1C-11L1,1C-11L1 vo p 1C-174,1C-174,1C-174 V8 1C-07,10-07,1C-07 V2 -A-- is-11,ic-11L1-01,1c-11L1-01 VO -1- 1C-174,Plan:1C-174a,1C-174a(wp01)V2 -I-- 1C-07,1C-07A,1C-07A VO $ 1C-11,1C-11L1-02,1C-11L1-02 VO -8- 1C-174,Plan:1C-174a L1(wp01),1C-174a L1(wp01)V1 --0- 1C-07,1C-07AL1,1C-07AL1 VO -0- 1C-12,1C-12,1C-12 V6 -A- 1C-178,10-178,1C-178 V1 -9- 1C-07,1C-07ALIPB1,1C-07AL1PB1 VO - 1C-13,1C-13,1C-13 VO -9- 1C-178,1C-178L1PB1,1C-178L1PB1 V1 -e- 1C-07,1C-07APB1,1C-07APB1 VO -I- 1C-16,1C-16,1C-16 VO - 1C-18,1C-18,10-18 Vo 10-08,1C-08,1C-08 V4 -0- 1C-170,1C-170,10-170 V2 -e_ Plan:1C-150,Plan:1C-150,1C-150wp13 VO -B- 1C-08,1C-08L1,1C-08L1 V2 -e-- 1C-170,1C-170PB1,1C-170PB1 V2 $ Plan:1C-152(1C-C),Plan 1C-152,1C-152(wp07)VO - 1C-08,1C-06L1-01,1C-08L1-01 V1 -X- 1C-172,1C-172,1C-172 VI - Plan:1C-153(1C-E),Plan 1C-153,10-153(wp05)VO 1C-08,1C-08L1 P81,1C-08L1PB1 V3 --8- 1C-172,1C-172A,1C-172A V0 -0- Plan:1C-154(1C-D),Plan 1C-154,10-154(wp05)VO - 1C-09,1C-09,1C-09 V3 -e- 10-172,1C-172AL1,1C-172AL1 VO -X- EW4,EW4,EW4 VO 1C-109,1C-109,1C-109 V4 -0-- 1C-172,1C-172AL2,1C-172AL2 VO $ 1C-151wp15 -9- 1C-109,1C-109L1,1C-109L1 V2 -I-- 1C-172,1C-172AL2PB1,1C-172AL2PB1 VO ConocoPhillips 1 C-151 wp 15 Schlumberger Alaska ANTI-COLLISION SETTINGS 14:41,August 02 2013 Interpolation Method: MD,interval:25.00 Depth Range From: 28.00 To 12541.21 Results Limited By: Centre Distance: 1451.31 GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 2050.00 1C-151wp15(Plan: 1C-151) CB-GYRO-SS 2050.00 2446.03 1C-151wp15(Plan: 1C-151) MWD+IFR-AK-CAZ-SC 2446.03 4628.18 1C-151wp15(Plan: 1C-151) MWD+IFR-AK-CAZ-SC 4628.18 12541.21 1C-151wp15 (Plan: 1C-151) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2427.30 2446.03 13-3/8"x 16" 13-3/8 3791.30 4628.18 9-5/8"x 12-1/4" 9-5/8 12541.21 4-1/2"x 6-3/4" 4-1/2 N '4', b ,_ U U_ - aim \ I ,I/ / \ 1 _ 1 l 1 1a I I 0IIIII 2 - I I _2 lir 1 \ / \. / _I 0 _ 0 I I 1 1 1 1 I 1 I I I I I I 1 1 1 I I 1 1 I 1 I 1 1 1 1 ' 1 I 1 I I I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -8- 1C-05,1C-05,1C-05 V2 .--T-- 1C-11,1C-11,1C-11 VO -6- 1C-172,1C-172AL2PB2,1C-172AL2PB2 VO -9- 1C-06,1C-06,IC-06 V2 -e- 1611,10-11L1,16t1L1 VO -A- 1C-174,1C-174,1C-174 V8 - 1C-07,1C-07,1C-07 V2 -A-- 1C-11,1C-11L1-01,1C-11L1-01 VO - 10-174,Plan:IC-174a,1C-174a(wp01)V2 1C-07,1C-07A,1C-07A VO -9- 1C-11,1C-11L1-02,1C-11L1-02 VO -9- 16174,Plan:1C-174a L1(wp01),1C-174a L1(w)01)V1 - 10-07,1C-07AL1,1C-07AL1 VO -9- 1612,1C-12,1C-12 V6 -A- 16178,1C-178,1C-178 V1 - 1C-07,1C-07AL1PB1,1C-07ALIPB1 VO -1--- 1613,1C-13,IC-13 VO -e- 1C-178,1C-178L1PB1,1C-178L1PB1 V1 - 1C-07,1C-07APB1,1C-07APB1 VO -1- 1C-16,1C-16,1C-16 VO -X- 1618,1C-18,1C-t8 V0 --1- 1C-08,1C-08,1C-08 V4 ---e- 1C-170,1C-170,1C-170 V2 -e- Plan:16150,Plan:1C-150,1C-150wp13 VO -9- 10-08,1C-08L1,1C-08L1 V2 --9-- 1C-170,1C-170PB1,1C-170PB1 V2 -e- Plan:16152(IC-C),Plan 1C-152,1C-152(wp07)VO - 1C-08,1C-08L1-01,1C-08L1-01 VI - 1C-172,1C-172,IC-172 VI - Plan:1C-153(1C-E),Plan 1C-153,1C-153(wp05)VO 1C-08,IC-08L1PB1,1C-08LIPB1 V3 ---e- 16172,1C-172A,1C-172A VO -.0,-- Plan:1C-154(1C-D),Plan 1C-154,1C-154(wp05)VO 1C-09,1C-09,1C-09 V3 ---9- 1C-172,1C-172AL1,1C-172AL1 VO -X- EW4,EW4,EW4 VO 1C-109,1C-109,1C-109 V4 -0- 1C-172,1C-172AL2,1C-172AL2 VO -D- IC-151wp15 1C-109,IC-109L1,1C-109L1 V2 --I-- 1C-172,1C-172AL2PBI,1C-172AL2PB1 VO Sec Inc Azi TVD +N/ +E/-W DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 0.. 0.00 0.00 0.00 0.00 - From MD-0,,.-. .o MD 2 250.00 0.00 0.00 250.00 0.06 0.00 0.00 0.00 0.00 1 C-151 wp15 3 550.31 4.50 330.00 550.00 10.22 -5.90 1.50 330.00 11.40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 28.00 To 1001.00 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 50.75 2.00 170.00 103.30 6 2108.12 576 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 250 350 3650 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 14:42.August 02 2013 350 450 4150 4650 9 10 4628.18 81.085 349.10 35 65.00 350.85 791.30 1780.52 -364.85 4.00 -6.273.77 1401.08 -297.50 0.00 1 1430.34 1 1814.28 1C-151 MW 31Jul13 Heel 450 - 550 4650 - 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -42457 3.00 0.00 212926 550 ��±± 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 a-OBAL FILTER APPLIED: 650 - 650 6150 7150 14 6097.58 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 Ti ----...-....----.---• 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 387872 �m F.o4D m T soaey�e4 roof __ 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 28.0e oour0.151vg15(Plan:1c-151$6-GVFPss 1050 _ - 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 2050002446m c-151m15lr1 r:1C15114WD.IFR-accazsc 1250 1450 9150 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 2446.034628.181C-151v415Plag 1C -aacnzsc10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 46281.2541.21 1w514,15(Rev 1c-15114vD+lFA-ac-cusc 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 1450 1650 10150 12150 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 CASING DEraLs 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 TVD MD Name size 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.30146.03 133/4 x 16' 13-3/8 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 3781 3028.185'8'x 12-1/4'9-5'8 2 1013.43 91.36 347.99 3848. 7 7826.71 -1956.81 3.00 -0.17 8066.48 12541.21 4-1/2 x53/4-4-12 2650 - 3150 27 111187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 834035 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 10-151 DL 16Jul13 17 32 12050.52 79.28 348.04 387220 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 7928 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 10-151 DL 16Jul13 T8 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 10-151 DL 16Jul13 TD 0/360 150 -30/330 140 30 130 120 110 100 90 -60/30r 80 60 70 • 60 50 • 40 -90/270° • ;� 90 G) - - ice. ��1s►,z.IO�V 1/01114,, 4Q__- 06 141:111110104' ���iiii 6 4%110;7,,ts: 40 .\..t4Z))004 k.:'4444, al lb --reAs. -120/240 _� ` ®4��4,'gi� ,�i J 80 `:=�.:1,ib.11,Aa�,_ rr 120 V. our ` , -- 4"..-10-400.-.- �taa. r•�0 q,� ♦!� ��f�I1. 3(w•1 1 t'��s'��G�'4011Li 0 Irl, r,j,,:., 150/210 - - "! ;. 150 1 -180/180 -e- , -2- , -� -e 10P8200 $ P „5e 10.150871300 $ 1CD�4.746.0(16.04 02 -a- - -e- 1 V2 4-to- -e- P.16-152 1164,P1.n 16.752.16.,52,.007160 -fr , 9 t -A- 1`16 X11-01 64 -F t , 48 0007 V2 -?E- P 1C-153(10P),Plan 1„55,,,5019005,00 -$- 1 0133 IC-07 -6- , 1Pe103 $ , 0200 $ $ ti 11(8701,,1,174811 58701)VI P 16.152(16-0,PUP 1,1 .,,1 V.v./00 -a- -e 76 $ 1F -fr 1� � 10 4 $ , 4 a-- , + , O';e-;000 .e -e- 31P6,71 $ 1„5,7,5 a ,a7.14a7,�e,.,,47.Pe100 $ ,�1�,1414.1,1,,421102 -� ,�,e,lc,,,,,,400 -.- ;F1,2.14172712P6,.,,,22412P61W ->E- �<,3,1813,„1404 Sec MD Inc Azi TVD +NI +E/-W DLeg TFace Sec Target 1 2800 0.00 0.00 28.00 0.. 0.00 0.00 0.00 0.00 • 1 C-151 w p 15 From MO-C.,._ .0 MD 2 3 5 250.0 0.00 0.00 250.00 0.0e 0.31 4.50 330.00 550.00 10.220.00 0.22 .00 -5.90 0.00.5 330.0 11.40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 1 000,00 To 2001.00 26 250 3150 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 6 2108.12 5.76 340.41 2096.00 178.88 -81170.00 .18 0.00 0.00 193.80 250 - 350 3650 - 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 9 4223.5 65.00 350.5 373.77 1401.08 -297.50 0.00 0.0 1430.34 14:42,August 02 2013 350 450 4150 4650 10 4628.18 81.08 349.10 3791.30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Jul13 Heel 450 - 550 4650 - 5150 II 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.28 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 OBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 10-151 DL 16Jul13 T1 -- •- •----• 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 3878.72 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 m oo 2�so.m l�ol i.yis lel:lGtsr vaoss 1050 --- 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 E48. 50002443.031C.151rg15(No IG151 D.IFnMccnzsc 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 m 4%11.18 16151we (Plan 16151 odea-Nccnzsc1250 - 1450 9150 - 10150208432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.0 0.27 5589.80 16751 DL 16Jul13 T3 2flte2541 21 16151 wy15(Flax 1C -AK-CAZSC 1450 1650 10150 12150 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 CNG DETAILS 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 14 TVD MD Nana sue 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3.48 CO 133'8 016 1339 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 3791.37428.1.5e-x,2.1f4 Asa 26 10913.43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 12541.214-1/2x53/4.412 2650 - 3150 _ 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 T7 32 12050.52 79.28 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 79.28 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 TO 35 12313.0 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 390420 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/360 150 -30/330 140 �J+ 30 130 %0/0��®r 120 'sall41Am�R .� ii.to z. ! V 4 „,...,..,„... p.,.....,,, ili P..1 .%114.li ItW4NITA hl Lira 7 � tt 60/300 -iia.�a�>�,► ,.......4 i�41/��4�4►�1'.e \%►/�\��I� 60 .=, tittiefaTAV ���I AA .t iv skt. ,°ev\��� ♦ ` tm;... T:.;,..,„Ii.,.,-.„....__. ..�\ I�' X1.1 1:�N.,....411.1/4., �•'♦, fp`-i 4� 41- i:'- m 'ar igitt - 4ll►YPi1r �t1`• `4,l I r'x�/ 9 '.46-01. i Awn � :��1 it 41,,,,�\��,�►��Ny6-tr,4,420,t),:,1•11.4 .r ��`. Iry �/,'�' A , "i,..,a%4,.„,p.z..,,;,..gp,,-,----v,....„doc,ort,,,-,,.„s,lr,sl,,v,,,_4,T.: ,..,,,..,,,,, ofir, , „..,,,,,:.... , , ".„„ \ p,f tAy4,41„*At,t,t4s--- Notiog.pionok4,„,ipf "lip*, ii,wilt iih,,, , ,valp„01.4Pj" ' 4.1111A ..---ikigi,‘14p,..,1440; ofioll pi ,7n ASA A orii! "IMPlit. O.W410'i.lr r ...,,,,,.w4.1,37,71 ir.-.....7,„,,,,tscrim ....,., � 4 As ,, ► V \ ,r : 4i i ifi. � 11I11100 1 %►i=i.� N,470, / 4,4rA,7 A/4;110NN., 40-eAkw,,i-,...104.-24/11ke Al \ littA f#' . is,,..*:-_,,..kgw-„.,*,--.4.2--wAil Nkigkilli avIV1 4 diltdriVtitizie',I ..ANIdt `" IieI ®fiti / �I4444 % '�-120/240 ' Irri vU ♦. �W144; � 120 ,'� ► ' jA\ i., ,mo' ��s �* ✓ 1��S-:' L' A- '� / am am� 1 � /o � mmti - u, :-'_6.:',7$114/1/411111,' . �,pole Ng 17�i. �%! � 1 /i%��s ` f , _ t ,0rr ; gar - .lilr7' /_!:.:(141,14.4n `I® •-kr_ f 6i y -150/210 ,r44f,„,„#-.14140-497201..,-i..-4 .*0"`� �-‘11,1,1•4.� 150 e-iii� c f4 -- -._fit' -180/180 $ 10os+0.8,+0es32 } + } + $ +wn,w+n.+c+nw -� 1o,n.+unx2Pm,+uleuzPex vo $ P.+a+so,N..:+e,su 10.150.13 VO $ 0006,rope,we4w $ ,cae.icauEeaniw $ $ + ro,itowes1n01n501w -a- wara+cw.ncv4w $ P s:(104N 0.0.ic+ss,wassf.wnvs -� .,uar,we.w $ ,cae waxim,waeuai v+ -fr + ai+�4w+w dE 1 n.IC-in v, t 1on..ro.IC on.wnal vogw } v sauc4a.waasx ICass 1.906)00 -9- 0.070.0006.00 -� it.,10440/221,10041.170.1 w $ 10A1,,cuuo:,+o-nuasw $ 1 $ + u 7.903 IC-120u c+w1)v, $ r IC-.(10-70.7 +o-w,,o-n.)0006). -} w -� 10419,1044,was. $ +caz 1o+o+ueve $ 10.123.10-1720.1.1.10.1720.190 -�- C 44- Eu,,ew.,two. $ wa.,iw.arre carri+ra+vs } + } +c+a,lwa,+cnw t , nno-+nuznanu2w $ +C-nnca.x+wx�C-120.120.100 $ 1MO two $ wan wm.ve�.,ca..Pe+w $ ic106,�uox�,wiwuw -} +o-+4+ua+wevo 1c+n,+c+rpuca+,10.1730.2.1 v. -){- w1e.w7e10-121. - Sec MD Inc Azi TVD +IV, +FJ-W DLegacTF��arget From MD L. .o MD 1 28.00 0.00 0.00 28.00 0. 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.0.. 0.00 0.00 0.00 0.00 1 C-1 51 wp15 3 550.31 4.50 330.00 550.00 10.22 -5.90 1.50 330.00 11.40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 2000.00 To 3001.00 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 170.00 103.30 6 2108.12 5.76 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 250 - 350 3650 -- 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 9 4223.5 65.00 350.85 373.77 1401.08 -297.50 0.00 0.00 1430.34 14:42.August 02 2013 350 450 4150 4650 10 4628.18 81.08 349.110 3791.30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Jul13 Heel 450 - 550 4650 - 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.26 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 • Ct.OBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 TI ---•••-•••---••••• 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 3878.72 aPm Pa1N®n rC s111L•.rpl.1 TCoi _ 17 7531.62 88.28 348.00 3804,90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 a1370"Doz�so.001C-151v.p15(PlaI:10-151 n-DYROSs 1050 _. 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 2050.802446031C-1S1xp15(Plat 10-151aWD.Im-AK-cnzsc 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 2446.03 4828.18 IC.1512,015(Ftat IC-151 D.IFR-acceZs1250 c 1450 9150 10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 4628182541 21 1C-151ep15(Plat:1F151MYD.IFn-a(-CAZSC 1450 - 1650 101550 - 1215.10 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 c.1SNc DET.'s 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 1650 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 TVD MD Nana sae 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.31144803 133/8'.16• 13-3/8 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 31919R2fl2sYe x6516-al�r2 26 10913,43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 2650 - 3150 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 1 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 T7 32 12050.52 79.28 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 79.28 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 T8 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/,.$ ,.I ialibill -30/330 ■ 140�'�._ 30 . ■ 13� ��,.;4�, 1 ,��. ..� 13 • 10IS *$ -60/300 80 \�,;90 1.w .,`` 60 60 L ‘1111W14,NAtixi,..,411111111. --47 41, 50 40 0,. -Te.1:_I 1 k\-411 Ili, 40 . l !Ar• 7'-------20c i \ TAI *dr -- -90/270 �,.' / 90 3, till j1i/ �,�•i -120/240 •. .��w��'.''`' +, 120 'lir9rearallilliO / C-1tWp0011 / 1. '111klikli, `,'.��./d 111014WAWAIIFAIWP Ilk --- 41111r0 -150/210 _-����/ 150 t -180/180 -0- , -8 .� , -} a2PE2Ve a P IC-Iso,.,sCry,3Vv -$ , -9- ; 1.15481.1 V2 $ $ , IV2 -lam 9 P 52000-C,Pun 1.152,10-1525007)30 -ltr , $ , 1,10542241 vi -� 9f 4P.W,IV2 -s- P 53(1C-5,Plan 1.15,1.1530.05)O -} a 1Ca7e We7AVo -fr 1.05,1.00,51.1.051.1P81 VC $ 1.111.1-02,1.111,02 VO $ $ u.01,1.17,1a a 5501)V. -9- P 54(Ica,,n.n1C.I5.,1C-IS..m05)CC -4- -fr t .,1C0e COe� $ ' $ 4- EWAIEW.,EW.CO $ 0 -•)E-- t } 1.13,IU,IC-I2 Co .� .17252.IO-IlCa2.V0 -� 7OLIP81,1.173LIPSI W $ IC-151.I5 -01- )COI,1.07A^EI.IC-0AM VO -5- '0...IC 1o2Ll.lc ISSLI v2 } 0181.18,Ic.v. -X- ,0-272,.I0.2nou2P212:20-122/ SI W -1- ,c1(..,4 1.19 v0 - Sec MD Inc Azi TVD +N/ +E/-W DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 0.. 0.00 0.00 0.00 0.00 • 1 C-151 wp15 From MD L. MD 2 3 5 250.0 0.00 0.00 250.00 0.31 4.50 33000 550.00 10.22 5.90 1.50 330.00 .00 11.40 4 904.01 11.58 330.00 900.00 53.04 -30,62 2.00 0.00 59.16 3000.00 To 5001.00 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 6 2108.12 5.76 340.41 2096.00 178.88 -81.18170.00 0.00 0.00 193.80 250 - 350 3650 -- 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 35085 3673.04 1399.53 -297.25 0.00 0.00 1428.77 1430.34 14:43,August 02 2013 350 450 4150 4650 9 10 4628.18 81. 08 349.5 65.00 10 35 791.30 1780.52 -364.85 4 00 -6.273.77 1401.08 -297.50 0.00 1 1814. 28 1C-151 MW 31Jul13 Heel 450 - 550 4650 - 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 212926 13 5515.54 91.93 332.10 3807.79 2626.30 -613,19 3.00 -83.41 2695.52 G-OBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 T1 __•.•_••..__••••• 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -17988 3878.72 gB�24 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 �k0os�o.aft 1P151xp15(Flan:1C-15168-GVOOSS 1050 --- 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 205000 2448 03 10.1510,15 Flat:1C-151�tWD.rca-01(-COzsc 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442,21 244103 4828.1810-1514,15(Flan:1C-1518114/D.IFFI-ex-cAzsc 1250 - 1450 9150 - 10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 4629182541.21 1C-15104,15(Flan:10.151MWD.IF13-Al(-CAZSC 1450 1650 10150 12150 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 COSNG DETNLS 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 14 TVD MD Warne sae 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3814903 1331e x 16'13-379 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0,00 7986.34 1C-151 DL 16Jul13 T5 379134628.10-51'x 12-1/d'459 26 10913.43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 12541.214-1/2 x63i4.4-1rz 2650 - 3150 27 11187,74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 834035 ---- 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 838577 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416,10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0,00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 T7 32 12050.52 79.28 348,04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 79.28 348.04 3875,89 8956,42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 T8 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/360 150 -30/330 140 30 130 120 110 100 • 90 -60/300 80 60 lial 70 60 50 40 -90/270 Milris- 90 11111 111 50 60 70 120/2401111 11111111111111111 80 120 90 100 110 120 130 -150/210 140 150 150 -180/180 9 -4- ,Cp,1Ca41000 V4 .4- 1,10.1,04 -} 'A- L2P62VO 9 F G,SO,C150no1300 $ •E} ,Ca6,100*11,,Go7L1 V2 -0- 1,1G,1L,VO -� 1 02 -� ; 9 P 52)ICC1'R.n 10152,1C-1SO 70,07100 -t- lc.10.05, 00702 $ , 1,10.11001,10-111.10,00 4& C.17201Po .1- , 2.0,01)02 .4- P 53(,CE).Pan IC-153,,C-1534-05)00 4- -6- , ,PB1 V3 $ a4 V4 -49 , >21,10.172A V0 $ L�70,1)IC'174.0 nwn VI -} P1)..1av)100)P.n,a154,1,154(.05)00 1C I000 •} C -8- IC r2,10-17200.1G112AL100 4- 10 40 154 EW4,FM CO 1 7,1Ca7011PB,1100720170100 .1.. 3- IC.13,1413,1L.13 00 $ t 1201 G 2, ,12 $01004 731.1P311 VI $ IC151.,15 -0- 1047,10.07241,1007074100 -8- 10-109,10.10011,10.1133 V2 -3- 1C,e,ICAO,/GAO 30 -4- IC-,72.1GIMMIPB,,,01TY22B1 V0 -X- 10101410,10.,5 V0 AMIMIII ♦ Sec MD Inc Azi ND +N1 171 DLeg TFace )/Sec target 1 28.00 0.00 0.00 29.00 0. 0.00 0.00 0.00 0.00 1 C-151 w p 15 From MD-C. MD 2 3 550.250. 0.00 0.00 250.00 31 4.50 330.00 550.00 10.22 -5.90 1.50 330.00 .00 11.40 • 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 5000.00 To 10001.0 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 170.00 103.30 6 2108.12 5.76 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 250 - 350 3650 -" 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 14:44,August 02 2013 350 450 4150 4650 9 10 4628.18 81 .08 349.5 65.00 $5 10 3793 1 1430.34 .30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Ju113 Heel 450 - 550 4650 - 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.26 _ 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 ' GLOBAL FILTER APPLIED. 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 Ti -•-•••-••••-- -- 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 3878.72 g31h F1onD0.1 s111vavmwl roof 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 28.00ro-151w%(Flan:1w51cacvaoss 1050 _7777... 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 2050002446.0310-1512y15(7000:1w590W0.IFa-00-c0z0c 1250 1450 9150 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 w 2448034628.18151wp15 Maw 1c-181 D+IFR-nx-cnzsc10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 as281.2541.2110-151 wy15(Flan:1c451MwD+iFa-accazsc 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 1450 1650 10150 12150 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 5834.29 008/40 DETAILS 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 TVD MD nano size 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3146603 13-3/8 2 16. 13-3/8 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 37911.21 1z-v4•9-5/89-5/812541.21 a-1/2 xs-3r4.4-1rt 26 10913.43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 • 1zsa -vz 2650 - 3150 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 17 32 12050.52 79.28 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 79.28 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 18 • 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/360 150 -- -30/330 140 - 30 130 �� 120 \\ • 110 � � \\ 100 \ � 90 �, 60/300• 80 60 \70 60 \ \ 50 \ 40 \ � 1 3 1 2' , � \ i -90 11 /270 90 2 / / 3 % / • 4. / // 50 j 60 __________/. / 70 j -120/240 80 / 120 90 100 , / 110 , , i 120 130 -150/210 140 150 150 -180/180 9 ,. -a- i- , 1. -� 1. 00202 9 .e. , $ 9 , 9 172 -e� 9 P2 0 700).P ;.152,1V.;524.�ve -9- , -43 ; -IS- , - 7..1,01)02 } 6. 531,004,Flan 10,5310.153tval v. } , .07a cco>Ava -8- , Ie91 VS $ 0202 $ $ uCb001110.1748 a l.wn 01$ Marc5.nw1...�1.144.m'u40505400 -9- 1c -�- ,Pm $ c $ ,c 10 - 4+ a o 00 $ 1c o -F- 10- } 10- -e- , 9 , 1781.11 v' $ 1c 151.,15 .6- 1007,100awe1,1.072001 00 $ ,0.,00,10.10x1.1cwou 02 } 10,1o,e,lwe v - { .4 1.072,12.17zuz0e�1.172/4.20131 00 1010.1013.1018 v0 • Sec MD Inc Azi ND +N +FJ-W DLeg TFace VSec Target From MD L. .o MD 1 28.00 0.00 0.00 28.00 0. 0.00 0.00 0.00 0.00 1 4.50 330.00 550.00 10.22 -5.90 1.50 330 00 11 1 C-151 w p 15 3 550.3 .40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 10000.00 To 12541• 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 170.00 103.30 6 2108.12 5.76 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 _ 250 - 350 3650 - -- 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 E350 - 450 4150 - 4650 9 4223.95 65.00 350.85 3673.77 1401.08 -297.50 0.00 0.00 1430.34 14:44,Auq!lst 02 2013 10 4628.18 81.08 349.10 3791.30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Jul13 Heel 450 550 4650 5150 11 4648.18 81.08 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.26 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 GLOBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 6.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 T1 •••-•••-••••----••••-• 850 1050 7150 i 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 387872 �epn n0�m n r0 sarveymean Tool 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 zero 2r5a.aa 1c151vg15(Nan:1C-151-360-0S 1050 - 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 2050.002446.031G51v7815(F801:10-15120W0020-00-05zs0 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 2446.03 4629.18 1C-151,14,15(Flan:1c-151y1WD,iFa-a<-Cn20C 1250 - 1450 9150 - 10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 4629.192541.21 1c151x915(Nan:10.151y1wD,iFa-ac-cxsc 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 1450 - 1650 10150 - 12150 22 8677.67 94.66 348.01 3819.11 5640.31 -1492.06 0.00 0.00 583429 CASNG DETaLS 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 DID MD Nana son 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3E446M 13-3/2812 13-378 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 T5 370125541.1..tav2x 12-v4 acrez1anz x63/4.4-1Y2 26 10913,43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 i22650 - 3150 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 • 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 84.00 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 T7 32 12050.52 79.28 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 7928 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 T8 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/360 150 -30/3300111111.140 30 130 120 110 100 90 -60/300IA . 80 60 • 40 50 60 i i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 mio m iiiiiiiiiiimuiliimi 70 -120/240 80 120 • 90 100 110 120 130 • -150/210 140 150 150 -180/180 a 10 •9- 1.003-- 1c 4} 1c ..tr L2P32Ve 4 as $ , $ , -9- , 9 162 $ 6- a 52ocCO.Paxiccss�o152 i-c07)60 -fr , 6- , -fr , -46- 1 -}- 7..(.,01)v2 -� a 5300.2),vanIc,5a 10.539905)vo ..}. , 0075.1027220 -Q- , 1ea193 $ ,c,,,, 2200 -9- , $ u 0,01).10.174.Cl(5301)v, $ a 54/1015/,a1-10w.,0122.505)60 -0. 1c ->4- ,coo $ IC- -13- 10 -fr 10 a 4v0 •t} 1c90 •4" 10-1oe,1.100,1.100 04 19.13, $ 10 9 1c 1751_1701 VI $ 10.1574915 9 202710,0754011027206120 -$ ,G1m,¢.104,11018110¢ -$- 1eie,to ,e vo - -} a.1c-7»u c m,7afe920 -X- 1c7810181.1a v0 - Sec MD Inc Azi ND +14 +E/-W DLeg TFace VSec Target From MD t. .o MD 1 2800 0.00 0.00 28.00 0. 0.00 0.00 0.00 0.00 1 C-151 wp152 3 250.00 0.00 0.00 250.00 550.31 4.50 330.00 550.00 10.22 0.00 5.90 1.50 330..00 00 .00 110.40 4 904.01 11.58 330.00 900.00 53.04 -30.62 2.00 0.00 59.16 10000.00 To 12541. 28 250 3150 - 3650 5 1204.01 5.76 340.41 1196.46 93.34 -50.75 2.00 170.00 103.30 6 2108.12 5.76 340.41 2096.00 178.88 -81.18 0.00 0.00 193.80 250 - 350 3650 4150 7 4022.21 65.00 350.85 3588.52 1220.57 -268.41 3.10 11.00 1248.46 8 4222.21 65.00 350.85 3673.04 1399.53 -297.25 0.00 0.00 1428.77 14:44,Auaust 02 2013 350 450 4150 4650 100 4 28.18 815 5.00 350.85 37.77 1401.08 -297.50 0.00 0.0 1430.34 . 08 349.10 3791.30 1780.52 -364.85 4.00 -6.21 1814.28 1C-151 MW 31Ju113 Heel 450 - 550 4650 - 5150 11 4648.18 8108 349.10 3794.40 1799.92 -368.58 0.00 0.00 1833.99 550 650 5150 6150 12 4945.40 90.00 349.10 3817.48 2090.61 -424.57 3.00 0.00 2129.26 13 5515.54 91.93 332.10 3807.79 2626.30 -613.19 3.00 -83.41 2695.52 a..OBAL FILTER APPLIED: 650 - 850 6150 7150 14 6097.59 91.93 332.10 3788.16 3140.41 -885.39 0.00 0.00 3262.56 15 6631.43 90.00 348.00 3779.10 3640.52 -1066.89 3.00 96.75 3792.60 1C-151 DL 16Jul13 Ti - •- -- -- 850 1050 7150 - 8150 16 6717.68 88.28 348.00 3780.40 3724.87 -1084.81 2.00 -179.88 3878.72 ay 17 7531.62 88.28 348.00 3804.90 4520.67 -1253.99 0.00 0.00 4691.19 1C-151 DL 16Jul13 T2 ��.00°2�so.0%-"17198,15rv151ep15(Plat:16,51$9-6n30-ss 1050 ---- 1250 8150 - 9150 18 7602.62 87.57 347.99 3807.48 4590.07 -1268.75 1.00 -179.35 4762.04 2050.002446.03161519615 Plan:16151 D.IF11-ac-CAzsc 19 8284.33 87.57 347.99 3836.44 5256.25 -1410.47 0.00 0.00 5442.21 244603 4626112541.21 161C-151.915 51 p115(non:16151 odFA-89 cn-SC 1250 1450 9150 10150 20 8432.16 92.00 348.01 3837.00 5400.82 -1441.20 3.00 0.27 5589.80 1C-151 DL 16Jul13 T3 1450 - 1650 10150 - 12150 21 8520.80 94.66 348.01 3831.85 5487.36 -1459.58 3.00 -0.06 5678.15 CASNG DETAILS 22 8677.67 94.66 34801 3819.11 5640.31 -1492.06 0.00 0.00 5834,29 1650 - 2150 12150 14150 23 8832.97 90.00 348.00 3812.80 5792.05 -1524.30 3.00 -179.93 5989.21 1C-151 DL 16Jul13 T4 3w MD wane size 24 8867.74 88.96 348.00 3813.12 5826.06 -1531.53 3.00 -179.81 6023.93 2427.3%46.03 13-3/8418 13-3/8 2150 2650 14150 - 16150 25 10833.17 88.96 348.00 3848.90 7748.21 -1940.11 0.00 0.00 7986.34 1C-151 DL 16Jul13 75 378112541.214-1/2 x46.Nr 9-5/8 1 26 10913.43 91.36 347.99 3848.67 7826.71 -1956.81 3.00 -0.17 8066.48 2650 - 3150 27 11187.74 91.36 347.99 3842.14 8094.95 -2013.86 0.00 0.00 8340.35 28 11233.24 90.00 348.01 3841.60 8139.44 -2023.32 3.00 179.36 8385.77 1C-151 DL 16Jul13 T6 29 11263.60 89.39 348.00 3841.76 8169.15 -2029.63 2.00 -179.49 8416.10 30 11798.79 89.39 348.00 3847.43 8692.62 -2140.87 0.00 0.00 8950.52 31 11933.61 8400 348.02 3855.20 8824.23 -2168.82 4.00 179.80 9084.88 1C-151 DL 16Jul13 17 32 12050.52 79.28 348.04 3872.20 8937.35 -2192.81 4.04 179.83 9200.35 33 12070.37 79.28 348.04 3875.89 8956.42 -2196.85 0.00 0.00 9219.82 34 12236.79 86.00 347.98 3897.20 9117.77 -2231.12 4.04 -0.46 9384.55 1C-151 DL 16Jul13 T8 35 12313.50 89.07 347.98 3900.50 9192.73 -2247.08 4.00 -0.07 9461.08 36 12541.13 89.07 347.98 3904.20 9415.33 -2294.49 0.00 0.00 9688.37 1C-151 DL 16Jul13 TD 0/360 300 -30/330 280 30 260 240 220 200 180 -60/300 60 I 10I r80 -90/270 90 Mr10: 10� 120/240 : 120 200 i 1141 iiiiiiiiiiiiiiiiiimimini II 220 240 260 -150/210 280 150 300 • -180/180 -4a ,Ca,c...10-..92 I -3- -0- , -o- , aP.200 0 P 6150,1300 -9- 14.11604.10-.4 V3 $ , VS 104 -fr , 9 P 02l`CC,I.�N wu.IC.,SV 00007190 -e- , ,1..793 -4} , _ `°40.0 01 VIC-I c., F• , a;,IC.IAVC -14r , $ .02 VO a -3- , B 7x,1C-h 0a -s- P °",3I,c. IC.„3,C.1546P.3,V. -9- 1 -f- ,Ca4.1004,woo 3/3 .q $ $ c-,79,00.ia6tO.I78 v, ncnx u,wµn 3/l $ P FM, MI0,nN 161vno1s.i.Posl3/o $ 14.07,,C.aa1PB1.I a7ALPB o } , o2,14.14.2. 7262 m -d- IC-174,IC.17..Ic17.917 -a- m14,P,4 Ivo • - 1407,IC.70PB1.IC07APOI COV c.4,1C lox 8 C 14 ICI.IC-0 Vo � 10-172,10.172A1,91,117 1 IC 1e 1614 10-15 Vo .0,080 3/l �- t I,IUIo.l1 3/2 -}- , } ,,U,7LLLTPB,V. -](- TRANSMITTAL LETTER CHECKLIST WELL NAME: , 6 ` 7S-1 PTD: Z./ o ( Development _Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: LL. L l,# POOL: -e--� t L 1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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