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214-148
• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QI`4. - 1_4- Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESC N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: 1.2r ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: dB% Date: I I p.5-1/Lt. /s/ Project Proofing BY: al �^- Date: !I �,SIN- /s/ YVIP Scanning Preparation (p—x 30 = I O + 3 =TOTAL PAGES 1 u 3 (Count does not include cover sheet) rid BY: 61:j.T....... Date: al g..,5 / /s/ Production Scanning Stage 1 Page Count from Scanned File: J Ti-i- (Count does include cover heet) Page Count Matches Number in Scanning Preparation: 1/ YES NO yve BY: 410 Date: i fa ✓ i 9i 1st Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES _ WY TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc • . o ! o I © N . 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C L) a) wcp IT). � E Q C: O £ E N u) E E o a o a o c i • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 3 0 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LOG r la.Well Status: Oi' ❑ Gas SPLUG ❑ Other El Abandoned ❑ Suspended lb.Well Class: "���"' 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: ,5/29/2015 214-148 3.Address: 7. Dat@,Spudded: tA42a-t0 15.API Number: P.O. Box 100360,Anchorage,AK 99501 5/ 2015 50-029-23528-62 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 282'FNL,419'FEL, Sec.23,T11 N, R10E, UM ,5/20/2015 KRU 1D-143L3 ' Top of Productive Interval: 9. KB(ft above MSL): 94' 17. Field/Pool(s): 880'FSL, 187'FEL, Sec. 14,T11 N, R10E, UM GL(ft above MSL): 67' Kuparuk River Field/West Sak Oil Poc Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4978'FNL, 189'FEL, Sec. 11,T11 N, R10E, UM ' 9075'MD/3739'TVD ADL 25650,25649 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 560671 y- 5959384 Zone- 4 ,9075'MD/3739'TVD 468,467 TPI: x- 560892 y- 5960548 Zone- 4 12. SSSV Depth MD/TVD 20.Thickness of Permafrost MD/TVD: Total Depth: x- 560849 y- 5965248 Zone- 4 nipple @ 737'MD/737'TVD 1650'MD/1636'TVD 5. Directional or Inclination Survey: Yes . 0(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) .4346'MD/3666'TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 94# H-40 27.5' 107.5' 27.5' 107.5' 40" 62.2 sx AS I,315 sx AS I 13,375" 68# L-80 29' 2489' 29' 2461' 16" 1208 sx Class G, 253 sx Cl G 9.625" 40# L-80 26' 5715' 26' 3921' 12.25" 435 sx Class G,537 sx CI G 4.5" 11.6# L-80 4335' 9042' 3664' 3738' 6.75" slotted liner 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5" 4255' 5786'MD/3921'TVD,6132'MD/ slotted liner from 4335'-9042'MD 3664'-3738'TVD .- -*tilt -,1, 3923'TVD,6649'MD/3944'TV[ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. ' 1;,11.4i..:--i Was hydraulic fracturing used during completion? Yes❑ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information M. ^4 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 24-Hour Rate Form 10-407 Revised 5/2015 V7 Ll O/2-0 � ' CONTINUEDON PAGE RBDMS )- JUL - 2 2015 Submit ORIGINIAL only / 28.CORE DATA Conventional Core Yes ❑ No ❑✓ Sidewall Cores: • ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1650' 1637' Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Top West Sak D 4346' 3666' Top West Sak A4 9075' 3739' Top West Sak A3 9075' 3739' Top West Sak A2 9075' 3739' NONE Formation at total depth: West Sak D 31. List of Attachments: Summary of Daily Operations,final directional survey,schematic, cement reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. L - Contact: David Lee @ 263-3741 Email: David.L.Lee(C77cop.com Printed Name: G. L.Alvord A Title: Alaska Drilling Manager Signature: ',I— Phone: 265-6120 Date: C Cat .[< INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP PROD 1D-143L3 ConocoPhillips Well Attributes Max Angle&MD TD A(asa Inc,. W Iib APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) CanoCaRuiGps 500292352862 WEST SAK PROD 93.98 8,062.14 9,075.0 ••. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-1D-143L3,6/29/20159 58:20 AM SSSV:NIPPLE I Last WO: 27.24 5/30/2015 Venwal schemat c(actuab Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._.... ...Last Tag: I Rev Reason:NEW WELL,ADD LATERALS Lt, smsmith 6/10/2015 L2,L3(all off mainbore) Casing Strings I IE 1C sing Description OD(in) ID(in) I Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WELen(I...Grade Top Thread HANGER;2t 2 L3 SLOTTED LINER 4 1/2 3.958 4,335 2 9041.6 3,737.5 11.60 L-80 IBTM Liner Details Nomina110 Top(ftKB) Top(TVD)(ftKB) Top Inc!(") Item Des Com (in) ,,,;„, ,. ,; „ , , 4,459.3 3,682.7' 84.15 Packer Freecap I FSC-14 6.38"OD Swell Packer,11.6#L-80 3.958 (Tubing) IBTM SN#50157611-01 ---------------------------------', ------- 4,525.7 3,687.8 87.11 Screen Tracerco Tracer Cartridge,5W 511 x 4W 563,11.6#, 3.958 1-911,T165F SN#07 5,942.9 3,712.7 90.18 Packer Freecap I FSC-14 6.38"OD Swell Packer,11.6#L-80 3.958 (Tubing) IBTM SN#50157610-03(5943) 6,125.1 3,716.0 87.96 Packer Freecap I FSC-14 6.38"OD Swell Packer,11.6#L-80 3.958 (Tubing) IBTM SN#50157611-03(6125) F AM. 6,191.2 3,718.5 87.93 Screen Tracerco Tracer Cartridge,514"511 x 4%"563,11.66, 3.958 CONDUCTOR;27.5107.5 5 T-920,T 716 SN#98 Notes:General&Safety h i iIEnd Date Annotation NIPPLE;737.1 ). NOTE: TEC Wire,22.0 LI iI GAS LIFT;2,412.4 t 3 SURFACE;29.0-2489.0 1 GAS LIFT,3.721.1 i, CENTRALIZER;4.112.6 ,! SLEEVE;4,113.6 CENTRALIZER;4,118.3 I . i V S GAUGE;4,179.3 T 7 .1. '. LOCATOR,4.235.9 ®kl: SEAL ASSY;4,236.6 '�i f1' 5 RAM LEM/SLZXP L3;4,220.5 a, 4,362.4 INTERMEDIATE-07-5,7t5.0 ; SEAL BORE DIVERTER L3; J; 4.339.8-4,423.6 L3 SLOTTED LINER;4,335.2- 9041.6 • • CanaeoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1D-143 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 3/29/2015 3:30:00 AM Rig Release: 5/30/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/28/2015 24 hr Summary Lay dn. 25 stds DP. Clear floor and rig down cellar scaffold. Prep rig for move.Move and spot rock washer and service modules. Prep pad. Move sub.off 1D-142. Prep pad. Lay herculite and mats. NU diverter w/crane. Move sub onto 1D-143. 00:00 01:45 1.75 0 0 MIRU MOVE PULD P PJSM-Lay down 25 stds DP out of derrick 01:45 02:45 1.00 0 0 MIRU MOVE RURD P PJSM-Lay down mousehole. Clear floor. Rig down scaffold in cellar. 02:45 04:45 2.00 0 0 MIRU MOVE RURD P PJSM-Blow down steam system. Disconnect air and steam lines between modules. Prep rig for move 04:45 06:00 1.25 0 0 MIRU MOVE MOB P PJSM-Move rock washer, pipe sheds and support modules. Spot on pad.. 06:00 09:00 3.00 0 0 MIRU MOVE PRLO P Clear and level pad around 1D-143 09:00 09:30 0.50 0 0 MIRU MOVE MOB P Move substructure off well 1D-142 and spot on pad 09:30 11:00 1.50 0 0 MIRU MOVE PRLO P Continue to clear and level pad around 1D-143 11:00 12:00 1.00 0 0 MIRU MOVE MOB P Lay herculite and set matting boards around cellar area 12:00 17:00 5.00 0 0 MIRU MOVE NUND P PJSM-NU adapter flange,diverter "T', annular BOP and diverter lines w/crane. 17:00 18:45 1.75 0 0 MIRU MOVE MOB P Move and spot substructure over well 1 D-143.. 18:45 22:00 3.25 0 0 MIRU MOVE MOB P Set mats for support modules. Spot support modules 22:00 23:30 1.50 0 0 MIRU MOVE MOB P Spot rock washer and pipe sheds 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Work on rig acceptance check list. 03/29/2015 Cont. rigging up-change saver sub-take on spud mud-load 5"DP in shed-Perform diverter test w/ AOGCC witnessing-PU 5"HWDP&5"DP&stand back. Hold pre spud meeting. MU BHA#1. Test surface lines. Clean out conductor f/92'MD t/107.5'MD. DDrlg surface hole f/107.5' MD t/197'MD. 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Cont. rigging up Accept rig @ 0330 hrs. 03:30 07:00 3.50 0 0 MIRU MOVE RURD P MU diverter equipment-Change saver sub-Take on spud mud 07:00 09:45 2.75 0 0 MIRU MOVE OTHR P Laod pipe shed w/5"DP&HWDP- Perform derrick inspection&service rig 1 Page 1 of 70 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:15 1.50 0 0 MIRU MOVE BOPE P Function test diverter-Knife vlave opened in 2 secs.-Hydril closed ing 23 secs. -Perform accumulator recovery test-Full charge pressure 2875 psi-Closed Annular-pressure 1750 psi-Start electric pump 2000 psi in 41 secs.-turn on air pump- back to ful charge in 169 secs. -N@ bottles 2000 psi-Test gas alarms- Tested flow show&pit gain/loss Test witnessed by Matt Herrera AOGCC Working on gas alarms lights- 11:15 19:00 7.75 0 0 MIRU MOVE PULD P PU&stand back 153 jts of 5"DP& 12 jts of 5"HWDP. Cont.working on gas alarms lights Rig on shore power @13:15 hrs 19:00 20:15 1.25 0 0 MIRU MOVE BHAH P Clear rig floor. Bring BHA tools and equip.to rig floor. Prep tools f/BHA 20:15 20:45 0.50 0 0 MIRU MOVE SFTY P Conduct pre spud meeting. 20:45 21:30 0.75 0 30 MIRU MOVE BHAH P Make up cleanout BHA as per DD 21:30 22:00 0.50 30 30 MIRU MOVE SEQP P Flood conductor.Test surface lines to 3500 psi/5 min. 22:00 22:15 0.25 30 108 MIRU MOVE DRLG P RIH and tag©92'MD. Clean out conductor f/92'MD t/107.5'MD 22:15 00:00 1.75 108 197 SURFA( DRILL DDRL P DDrIg 16"surface hole f/107.5'MD t/197' MD.ADT=1.5 hrs Bit hrs=1.5 PU=50K S0=50K ROT=48K TQ on=1K TQ off=.5K FO=73% WOB=5-8fK RPM=40 GPM=450 PSI=300 03/30/2015 POOH-MU BHA#2- Drill 16"hole f/197'MD t/1258'MD 00:00 00:30 0.50 197 37 SURFA( DRILL TRIP P POOH w/BHA#1 f/197'to 37' 00:30 01:15 0.75 37 37 SURFA( DRILL ELNE P RU Halliburton E-line unit for running Gyro Data gyro surveys 01:15 04:00 2.75 37 197 SURFA( DRILL BHAH P MU BHA#2-f/top of stab on motor arcVISIION , MWD,XO, UBHO, Stab, 3 NM flex DC's,saver sub,XO, to 197' 04:00 06:00 2.00 197 282 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 197'to 282' MD 282'TVD ADT- 1.82 hrs. Footage 85' WOB 10 k RPM 60 GPM 470 @ 620 psi w/60%FO String wt. PU 65 SO 65 ROT 50 Torque on/off btm.-1/.5 k Total bit hrs. 1.82 hrs Total jar hrs. 95.7 hrs Ran gyro survey @ 197'&282' — Page 2 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 282 563 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 282'to 563'MD 563'TVD ADT-5.65 hrs=ART-5.10 hrs. AST-.55 hrs.-Footage-281'-ECD 10.08 ppg WOB 15/20 k RPM 60 GPM 550 @ 700 psi String wt PU 69 SO 72 ROT 69 Torque on/off btm.-2/1k Total bit hrs. 7.45 hrs. Total jra hrs. 101.35 hrs Took guro surveys @282',375',467', 560' 12:00 18:00 6.00 563 936 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 563't/936'MD 936'TVD ADT-3.98 hrs=ART- 1.11 hrs. AST-2.87 hrs. -Footage-373'- ECD 9.88 ppg WOB 20/25 k RPM 60 GPM 600 @ 975 psi String wt PU 76 SO 79 ROT 77 Torque on/off btm.-3-5/1k Total bit hrs. 13.05 hrs. Total jra hrs. 105.33 hrs Took guro surveys @ 652', 743', 837',932' 18:00 00:00 6.00 936 1,258 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 936't/1258'MD 1252'TVD ADT-3.76 hrs=ART-.49 hrs.AST -3.27 hrs.-Footage-322'-ECD 9.90 ppg WOB 20/35 k RPM 60 GPM 520 @ 875 psi String wt PU 84 SO 82 ROT 84 Torque on/off btm.-3-5/1k Total bit hrs. 16.81 hrs. Total jra hrs. 109.09 hrs Took guro surveys @ 1027', 1120', 1213" 33/31/2015 Drill 16"surface hole f/1258'MD to TD @ 2500'MD.CBU x4, racking back a stand each BU. BROOH f/ 2151'-750'MD. Stand back HWDP&NMFC 750'-96'MD. 00:00 06:00 6.00 1,258 1,589 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 1258't/1589'MD 1577'TVD ADT-3.82 hrs=ART-.91 hrs.AST -2.91 hrs.-Footage-331'-ECD 10.04 ppg WOB 20/25 k RPM 60 GPM 608 @ 950 psi String wt PU 95 SO 93 ROT 95 Torque on/off btm.-4/1-2k Total bit hrs.20.63 hrs. Total jar hrs. 112.91 hrs Page 3 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 1,589 2,091 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 1589't/2091' MD 2068'TVD ADT-3.41 hrs=ART-3.07 hrs. AST-.34 hrs. -Footage-502'-ECD 10.30 ppg WOB 25/30 k RPM 60 GPM 700 @ 1350 psi String wt PU 105 SO 96 ROT 98 Torque on/off btm.-5-6/1-2k Total bit hrs.24.04 hrs. Total jar hrs. 116.32 hrs 12:00 16:30 4.50 2,091 2,500 SURFA( DRILL DDRL P Directional drilled 16"hole w/motor f/ 2091't/2500'MD 2471'TVD ADT-3.01 hrs=ART-1.08 hrs. AST- 1.93 hrs.-Footage-409'- ECD 10.32 ppg WOB 10/20 k RPM 60 GPM 700 © 1425 psi String wt PU 115 SO 99 ROT 106 Torque on/off btm.-5-7/2-4k Total bit hrs.27.05 hrs. Total jar hrs. 119.33 hrs 16:30 19:00 2.50 2,500 2,151 SURFA( CASING CIRC P CBU 4X @ 750-780 gpm, 1600-1700 psi,60 rpm,Tq 4-7K, FO 68%, racking back a stand each BU 2500'-2151'MD. 19:00 19:30 0.50 2,151 2,151 SURFA( CASING OWFF P Monitor well,static. (Blow down TD) 19:30 22:30 3.00 2,151 750 SURFA( CASING BKRM P PJSM, BROOH f/2151'-750'MD,650 gpm, 1200 psi,60 rpm,Tq 2-8K, FO 65%. 22:30 22:45 0.25 750 750 SURFA( CASING OWFF P Monitor well, static. (Blow down TD) 22:45 00:00 1.25 750 96 SURFA( CASING TRIP P PJSM,TOH on elevators f/750'-96' MD. Racking back 6 stands HWDP &NMFC. Calculated fill 15.2, actual 19.25 bbls. 34/01/2015 Finish laying down BHA 2. Perform dummy run with 13 3/8"casing hanger. Rig up and run 13 3/8"surface casing as per detail f/surface to 2489' MD. C&C mud system for cement. Cement surface casing as per program w/CIP©23:30 hrs. 00:00 02:00 2.00 96 0 SURFA( CASING BHAH P PJSM, lay down BHA 2 as per SLB DD. 02:00 02:30 0.50 0 0 SURFA( CASING BHAH P PJSM,clear&clean rig floor. 02:30 03:15 0.75 0 0 SURFA( CASING RURD P PJSM, mobilize centralizers, casing tools,&Volant CRT to rig floor. 03:15 03:45 0.50 0 0 SURFA( CASING RURD P PJSM, perform dummy run w/hanger &landing joint per Vetco Rep. 03:45 04:30 0.75 0 0 SURFA( CASING RURD P PJSM, rig up casing equipment& Volant CRT. 04:30 04:45 0.25 0 0 SURFA( CASING SFTY P PJSM for running 13 3/8"casing. 04:45 05:45 1.00 0 168 SURFA( CASING PUTB P Make up shoe/float track&test. surface to 168' MD. 05:45 08:30 2.75 168 1,014 SURFA( CASING PUTB P Continue running 13 3/8",68#, L-80, Hyd 563 casing f/168'-1014'MD. 08:30 09:15 0.75 1,014 1,014 SURFA( CASING CIRC P CBU staging up the pump 1-2 bpm, 100 psi, FO 33%, FCP 75 psi. Page 4 of 70 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:30 2.25 1,014 1,742 SURFA( CASING PUTB P Continue running 13 3/8",68#, L-80, Hyd 563 casing f/1014'-1742'MD. 11:30 12:30 1.00 1,742 1,742 SURFA( CASING CIRC P CBU staging up the pump 1-3 bpm, 110 psi, FO 40%, PU 135K, SO 120K. 12:30 13:45 1.25 1,742 2,174 SURFA( CASING PUTB P PJSM, continue running 13 3/8",68#, L-80, Hyd 563 casing f/1742'-2174' MD. 13:45 14:15 0.50 2,174 2,174 SURFA( CASING CIRC P Break circulation staging up the pump.5-2.5 bpm,50-120 psi, FO 38%, 32 bbls circulated. 14:15 15:15 1.00 2,174 2,413 SURFA( CASING PUTB P PJSM,continue running 13 3/8",68#, L-80, Hyd 563 casing f/2174'-2413' MD, calculated displacement 16.13, actual 15.94 bbls. 15:15 15:45 0.50 2,413 2,489 SURFA( CASING HOSO P PJSM, make up XO joint, hanger, & landing joint 2413'-2489'MD, PU 195K, SO 155K.Total of 57 centralizers&3 stop rings ran. Average make up torque 29K. 15:45 18:15 2.50 2,489 2,489 SURFA( CEMEN CIRC P Circulate&condition mud for cement job staging up the pump.5-6 bpm, 90-210 psi, FO 49%@ 6 bpm. 18:15 18:45 0.50 2,489 2,489 SURFA( CEMEN-RURD P PJSM, blow down TD, rig up cement hoses,valves, &sensators. 18:45 19:45 1.00 2,489 2,489 SURFA( CEMEN"CIRC P Circulate&condition mud for cement job @ 6 bpm, 350 psi, FO 42%. Hold PJSM with all involved contractors for cementing surface casing. 19:45 23:30 3.75 2,489 2,489 SURFA( CEMEN-CMNT P Line up to SLB. Pump 5 bbls H20, test lines to 4000 psi. Batch up& pump 75 bbls. of ChemWash @ 5 bpm,225 psi. Batch up&pump 76 bbls 10.5 ppg MudPush @ 5 bpm, 225 psi. Drop bottom plug. Batch up &pump 417 bbls of 11.0 ppg Lead cement @ 6.5 bpm, 350 psi. Batch up&pump 74 bbls of 12.0 ppg Tail cement @ 6.5 bpm, 350 psi. Drop top plug. Pump 10 bbls of H2O @ 5.5 bpm, 150 psi. Line up to rig& displace w/9.5 ppg mud @ 6.5 bpm, 400-650 psi, FO 49%. Bump plug w/ 3440 strokes. Pressure up to 1100 psi&hold for 5 minutes. Bleed off pressure&floats check good. CIP @ 23:30. 23:30 00:00 0.50 2,489 0 SURFA( CEMEN'WWWH P PJSM,flush stack&flow line w/ black water. Blow down cement lines. J4/02/2015 Nipple down surface diverter system. Install wellhead&test to 5000 psi. Nipple up BOPE. Test BOPE w/5" test jt witness waived by AOGCC Rep Johnnie Hill. Pick up BHA 3 for intermediate hole section to 114'MD. 00:00 02:30 2.50 0 0 SURFA( CEMEN RURD P PJSM, rig down cement equipment& lay down landing joint. Clear&clean cement equipment, along with rig floor. Page 5 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 0 0 SURFA( CEMEN"RURD P PJSM, lay down riser&clean out annular. 03:30 06:00 2.50 0 0 SURFA( CEMEN-NUND P PJSM, nipple down diverter equipment. Fire Drill CRT 94 sec @ 04:45 hrs 06:00 06:45 0.75 0 0 SURFA(WHDBO NUND P PJSM, clean&install hold down flange. 06:45 07:15 0.50 0 0 SURFA(WHDBO NUND P PJSM, mobilize well head to cellar area. 07:15 10:30 3.25 0 0 SURFA(WHDBO NUND P PJSM, change valve alignment, orient well head, &nipple up well head, as per Vetco Rep. 10:30 10:45 0.25 0 0 SURFA(WHDBO PRTS P PJSM,test seal sub to 2500 psi for 10 min. Good. 10:45 12:30 1.75 0 0 SURFA(WHDBO NUND P PJSM, nipple up BOPE, center stack, &install riser. 12:30 14:30 2.00 0 0 SURFA(WHDBO RURD P PJSM, rig up to test BOPE. 14:30 18:45 4.25 0 0 SURFA( WHDBO BOPE P PJSM,test BOPE w/5"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14 and manual kill.Test#2: Upper IBOP, HCR kill, CV 9, and 11. Test#3: Lower IBOP, CV 5,8 and 10. Test #4: Dart„ CV 4,6 and 7.Test#5: Floor valve and CV 2.Test#6: HCR choke,4"kill line Demco. Test#7: Manual choke valve and HCR kill. Test#8:Annular preventer tested to 250/2500 psi.Test#9: Lower pipe rams.Test#10: Blind rams and CV 3. Accumulator test: system pressure=2950 psi,After closing= 2000 psi,200 psi attained after 40 sec,full pressure attained after 132 sec, Five bottle nitrogen avg=2050 psi. The BOP test was waived witness, by AOGCC Rep Johnnie Hill. 18:45 20:00 1.25 0 0 SURFA(WHDBO RURD P PJSM, rig down test equipment, blow down lines&manifold. Set wear ring. 20:00 20:15 0.25 0 0 SURFA( CEMEN"BHAH P PJSM, mobilize BHA tools to rig floor. 20:15 21:15 1.00 0 0 SURFA( CEMEN-RURD T PJSM, rig up&pull wear ring to verify ID of 12.3125". Install wear ring. 21:15 23:30 2.25 0 114 SURFA( CEMEN'BHAH P PJSM,pick up BHA 3 as per SLB DD. 23:30 00:00 0.50 114 114 SURFA( CEMEN-SVRG P PJSM,service rig. 34/03/2015 Finish picking up picking up BHA 3.TIH to—2300'MD.Test casing to 3000 psi. Drill out plugs, float equipment,&shoe track. Drill 20'of new hole to 2520'MD. CBU for even MW. Perform LOT to 14.5 ppg EMW. Displace to 9.3+ppg LSND mud system. Directional drill intermediate hole section ahead to 2730' MD. Unable to slide directionally,decision made to TOH to check BHA.TOH f/2730'-30"MD. 00:00 00:45 0.75 114 144 SURFA( CEMEN-BHAH P PJSM,continue picking up BHA 3& prepare to load sources. 00:45 01:30 0.75 144 144 SURFA( CEMEN BHAH P PJSM, load sources as per SLB. Page 6 of 70 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 144 398 SURFA( CEMEN-BHAH P PJSM,TIH w/NMFC&2 stands of HWDP, changing out the jars. 02:30 03:30 1.00 398 398 SURFA( CEMEN-SVRG P PJSM, service rig. 03:30 04:00 0.50 398 1,055 SURFA( CEMENT PULD P PJSM, pick up 18jts of 5"DP, f/ 398'-1055' MD. 04:00 04:30 0.50 1,055 1,616 SURFA( CEMEN-TRIPP PJSM,TIH f/1055-1616'MD. 04:30 04:45 0.25 1,616 1,616 SURFA( CEMEN-DHEQ P Shallow test MWD as per SLB. 04:45 05:15 0.50 1,616 2,300 SURFA( CEMEN-TRIPP PJSM,TIH f/1616'-2300'MD. 05:15 05:30 0.25 2,300 2,350 SURFA( CEMEN COCF P Wash&ream f/2300'-2350', 600gpm, 1300 psi, FO 54%,20 rpm, TQ 0-10K, PU 100K, SO 85K, ROT 90K 05:30 05:45 0.25 2,350 2,350 SURFA( CEMEN CIRC P CBU©600 gpm, 1300 psi, FO 54 %, 20 rpm,Tq 0-15K. 05:45 06:00 0.25 2,350 2,265 SURFA( CEMEN-TRIP P PJSM, TOH f/2350'-2265'MD. Calculated displacement 29.36, actual 27.25 for trip in the hole. 06:00 06:45 0.75 2,265 2,265 SURFA( CEMEN-RURD P PJSM, rig up to test casing. 06:45 07:15 0.50 2,265 2,265 SURFA( CEMEN'PRTS P PJSM,test 13 3/8"casing to 3000 psi for 30 min, good. 07:15 07:30 0.25 2,265 2,265 SURFA( CEMEN RURD P Rig down test equipment. 07:30 07:45 0.25 2,265 2,360 SURFA( CEMEN"COCF P Wash&ream f/2265'-2360', 500gpm, 1300 psi, FO 54%,20 rpm, TQ 0-15K, PU 100K, SO 85K, ROT 90K. 07:45 10:00 2.25 2,360 2,500 SURFA( CEMEN"DRLG P Drill f/2360'-2500'MD, cleaning out cement, float equipment, &shoe track, 500gpm, 1000-1300 psi, FO 54%, 20-30 rpm, TQ 0-15K. 10:00 10:30 0.50 2,500 2,520 SURFA( CEMEN'DDRL P DDrill f/2500'-2520'MD,2487'TVD, ART.20, BIT.20,JARS 86.6, PU 115K, SO 86K, ROT 100K,TQ on 1-4K, off 1-2K, ECD 9.32, FO 54%, WOB 5-10K, 30 rpm, 500 gpm, 875 psi. 10:30 10:45 0.25 2,520 2,520 SURFA( CEMEN-CIRC P Circulate&condition @ 500 gpm, 875 psi, 30 rpm,Tq 1-2K. 10:45 11:00 0.25 2,520 2,451 SURFA( CEMEN-TRIP P PJSM,TOH f/2520'-2451'MD, blow down TD. 11:00 11:15 0.25 2,451 2,451 SURFA( CEMEN-RURD P PJSM, rig up to perform LOT/FIT. 11:15 11:45 0.50 2,451 2,451 SURFA( CEMEN LOT P PJSM, perform LOT to EMW of 14.5 ppg. Pressure applied 800 psi. 11:45 12:00 0.25 2,451 2,451 INTRM1 DRILL RURD P PJSM, rig down test equipment, blow down kill&choke line. 12:00 13:15 1.25 2,451 2,520 INTRM1 DRILL DISP P PJSM,displace well to LSND mud system. Pump 25 bbl hi-vis sweep, followed by 9.3+ppg LSND mud @ 7 bpm, 280 psi, FO 40%, 10 bpm, 500 psi, FO 50%. 13:15 13:30 0.25 2,520 2,520 INTRM1 DRILL OWFF P Monitor well,static. SPR @ 2520' MD,2487'TVD, MW 9.3+ppg, 13:15 hrs. #1 @ 30=80 @ 40=110 #2 @ 30=80 @ 40=120 Page 7 of 70 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/03/2015 24 hr Summary Finish picking up picking up BHA 3.TIH to—2300'MD. Test casing to 3000 psi. Drill out plugs, float equipment,&shoe track. Drill 20'of new hole to 2520'MD.CBU for even MW. Perform LOT to 14.5 ppg EMW. Displace to 9.3+ppg LSND mud system. Directional drill intermediate hole section ahead to 2730' MD. Unable to slide directionally,decision made to TOH to check BHA.TOH f/2730'-30"MD. 13:30 19:15 5.75 2,520 2,730 INTRM1 DRILL DDRL P DDrill f/2520'-2730'MD, 2692'TVD, ART.68,AST 2.97,ADT 3.65, BIT 3.85,JARS 90.25, PU 110K, SO 92K, ROT 102K, TQ on 4-6K,off 1-8K, ECD 9.73, FO 58%,WOB 1-5K, 60 rpm,685 gpm, 1000 psi. Could not slide to attain directional decision made to TOH. Blow down TD. 19:15 19:30 0.25 2,730 2,730 INTRM1 DRILL OWFF T Monitor well,static. 19:30 20:15 0.75 2,730 2,450 INTRM1 DRILL PMPO T PJSM, POOH f/2730'-2450' MD,2 bpm, 100 psi, PU 115K, SO 92K. 20:15 20:45 0.50 2,450 2,450 INTRM1 DRILL OWFF T Monitor well,static. 20:45 21:45 1.00 2,450 461 INTRM1 DRILL TRIP T PJSM,TOH f/2450'-461'MD, calculated fill 30.19, actual 30.94 bbls. 21:45 22:00 0.25 461 461 INTRMI DRILL OWFF T Monitor well, static. 22:00 22:30 0.50 461 114 INTRM1 DRILL BHAH T PJSM, rack back HWDP&NMFC. 22:30 23:00 0.50 114 114 INTRM1 DRILL BHAH T PJSM, lay down sources per SLB. 23:00 00:00 1.00 114 30 INTRM1 DRILL BHAH T Continue to lay down BHA 3 as per SLB. 04/04/2015 Finished laying down BHA 3. P/U BHA 4&TIH to 2730' MD. DDrill intermediate section f/2730'-4126' MD. 00:00 00:30 0.50 30 0 INTRM1 DRILL BHAH T PJSM, lay down motor&bit as per SLB DD. 00:30 01:15 0.75 0 0 INTRM1 DRILL BHAH T PJSM,clear&clean rig floor. 01:15 02:45 1.50 0 30 INTRM1 DRILL BHAH T PJSM, make up bit&motor. Break off battery on ADNvision, C/O in pipe shed. 02:45 04:15 1.50 30 114 INTRM1 DRILL BHAH T PJSM, pick up BHA 4 as per SLB. 04:15 05:15 1.00 114 114 INTRM1 DRILL BHAH T PJSM, load sources as per SLB. 05:15 06:00 0.75 114 398 INTRMI DRILL BHAH T PJSM,TIH w/NMFC, HWDP,&jars. 06:00 07:45 1.75 398 2,638 INTRMI DRILL TRIP T PJSM,TIH f/398'-2611'MD. Kick w/Tripping Drill CRT 98 sec @ 06:58 hrs. 07:45 08:00 0.25 2,638 2,730 INTRM1 DRILL REAM T Wash&ream f/2638'-2730'MD @ 550 gpm, 800 psi, FO 54%,30 rpm, Tq 0-5K. Page 8 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 2,730 3,040 INTRM1 DRILL DDRL P DDrill f/2730'-3040' MD,2984'TVD, ART.48,AST 1.57,ADT 2.05, BIT 2.05, JARS 92.3, PU 115K, SO 100K, ROT 110K, TQ on 3-5K, off 3-5K, ECD 9.88, FO 56%,WOB 1-5K, 30 rpm, 682 gpm, 1100 psi. SPR @ 3009' MD,2959'TVD, MW 9.3+ppg, 11:00 hrs. #1 @ 30=120 @ 40=170 #2 @ 30=140 @ 40=180 12:00 18:00 6.00 3,040 3,617 INTRM1 DRILL DDRL P DDrill f/3040'-3617'MD,3409'TVD, ART.52,AST 3.44,ADT 3.96, BIT 6.01,JARS 96.26, PU 120K, SO 104K, ROT 111K,TQ on 5-7K, off 4-7K, ECD 9.97, FO 58%,WOB 1-5K, 60 rpm, 650 gpm, 1275 psi. SPR @ 3570'MD, 3383'TVD, MW 9.4 ppg, 17:15 hrs. #1 @ 30=160 @ 40=210 #2 @ 30=170©40=210 Kick w/Drilling CRT 99 sec @ 14:00 hrs. 18:00 00:00 6.00 3,617 4,126 INTRM1 DRILL DDRL P DDrill f/3617'-4126'MD,3617'TVD, ART.85,AST 2.69,ADT 3.54, BIT 9.55,JARS 99.8, PU 117K, SO 100K, ROT 107K,TQ on 5-8K, off 3-5K, ECD 9.46, FO 58%,WOB 7-11K,60 rpm,675 gpm, 1500 psi. SPR @ 4120'MD, 3626'TVD, MW 9.4 ppg,23:45 hrs. #1 @ 30=200 @ 40=270 #2 @ 30=200 @ 40=260 34/05/2015 DDrill intermediate section to TD 5725'MD. Circulate BU 3X. Observe well with slight flow.Weight up& observe several times,f/9.5 to 10.1 ppg. Observe well static. 00:00 06:00 6.00 4,126 4,686 INTRM1 DRILL DDRL P DDrill f/4126'-4686'MD,3740'TVD, ART 1.96,AST 2.06,ADT 4.02, BIT 13.57,JARS 103.82, PU 120K, SO 96K, ROT 105K,TQ on 5-7K,off 3-5K, ECD 10.32, FO 59%,WOB 5-10K,60 rpm,677 gpm, 1400 psi. Spill Drill CRT 129 sec @ 04:52 hrs. 06:00 12:00 6.00 4,686 5,362 INTRM1 DRILL DDRL P DDrill f/4686-5362' MD, 3889'TVD, ART 2.98,AST.36,ADT 3.34, BIT 16.91,JARS 107.16, PU 118K, SO 100K, ROT 111K,TQ on 5-6K, off 4-5K, ECD 10.36, FO 59%,WOB 5-6K, 50 rpm,680 gpm, 1550 psi. Max gas 1714 SPR @ 5337'MD, 3880'TVD, MW 9.5 ppg, 11:00 hrs. #1 ©30=230©40=280 #2 @ 30=220 @ 40=270 _._ Page 9 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:15 3.25 5,362 5,710 INTRM1 DRILL DDRL P DDrill f/5362'-5710'MD, 3922'TVD, ART.72,AST 1.57,ADT 2.29, BIT 19.2, JARS 109.45, PU 120K, SO 98K, ROT 108K, TQ on 7-8K,off 3-5K, ECD 10.30, FO 59%,WOB 5-7K, 50 rpm, 680 gpm, 1750 psi. Max gas 259 15:15 16:30 1.25 5,710 5,710 INTRM1 DRILL CIRC P CBU @ 680 gpm, 1750 psi, 80 rpm, Tq 6-8K, PU 115K, SO 98K, ROT 108K. 16:30 16:45 0.25 5,710 5,725 INTRM1 DRILL DDRL P DDrill f/5710'-5725'MD,3922'TVD, ART.12,AST 0,ADT.12, BIT 19.32,JARS 109.57, PU 115K, SO 98K, ROT 108K, TQ on 7-8K,off 3-5K, ECD 10.30, FO 59%,WOB 5-7K, 50 rpm, 680 gpm, 1750 psi. Max gas 908 TD 5725'MD, 3922'TVD. 16:45 18:45 2.00 5,725 5,615 INTRM1 CASING CIRC P CBU 2X @ 675 gpm, 1650 psi, 50 rpm, Tq 6-8K, PU 115K, SO 98K, ROT 106K. Lay down a single&rack back a stand @ 1 BU, f/5725'-5615' MD. 18:45 19:30 0.75 5,615 5,615 INTRM1 CASING OWFF T Monitor well, observe flow. Decision made to weight up f/9.5-9.7 ppg. 19:30 21:15 1.75 5,615 5,725 INTRM1 CASING CIRC T PJSM,weight up mud system f/9.5- 9.7 ppg©675 gpm, 1650 psi, 50 rpm,Tq 6-8K.Tagged up on a ledge @ 5708' MD, reamed through several times to clean up. 21:15 21:45 0.50 5,725 5,725 INTRM1 CASING OWFF T Monitor well, observe less flow. Decision made to weight up f/9.7-9.9 ppg. 21:45 22:30 0.75 5,675 5,675 INTRMI CASING CIRC T PJSM,weight up mud system f/9.7- 9.9 ppg @ 675 gpm, 1650 psi,50 rpm,Tq 6-8K. 22:30 23:00 0.50 5,675 5,675 INTRM1 CASING OWFF T Monitor well, observe very slight flow. Decision made to weight up f/ 9.9-10.1 ppg. 23:00 23:45 0.75 5,675 5,675 INTRM1 CASING CIRC T PJSM,weight up mud system f/9.9- 10.1 ppg©675 gpm, 1775 psi, 50 rpm,Tq 6-8K. 23:45 00:00 0.25 5,675 5,675 INTRM1 CASING OWFF P Monitor well, static. X4/06/2015 Finish monitoring well, static. BROOH, MAD passing f/5675'to surface shoe. TOH f/shoe to surface. C/O upper rams to 9 5/8"&test. Rig up&run 9 5/8"intermediate casing to 382'MD. 00:00 00:15 0.25 5,675 5,675 INTRM1 CASING OWFF P Continue monitoring well for 30 min, static. 00:15 08:45 8.50 5,675 3,722 INTRMI CASING BKRM P PJSM, obtain SPR's, BROOH f/ 5675'-3722'MD @ 650 gpm, 1625 psi,60 rpm,Tq 5-9K,350 fph. SPR @ 5681'MD,3921'TVD, MW 10.1 ppg, 12:20 hrs. #1 @ 30=240 @ 40=300 #2©30=230 @ 40=290 Page 10 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 12:00 3.25 3,722 2,642 INTRM1 CASING BKRM P PJSM, BROOH f/3722'-2642'MD @ 650 gpm, 1625 psi,60 rpm,Tq 5-9K, 350-720 fph. Calculated fill 30, actual 26.52 bbls. 12:00 13:00 1.00 2,642 2,489 INTRM1 CASING CIRC P PJSM, CBU 675 gpm, 1300 psi, 50 rpm,Tq 4-6K, PU 98K, SO 95K, ROT 99K, f/2642'2589'MD. 13:00 13:15 0.25 2,489 2,489 INTRM1 CASING OWFF P Monitor well, static. 13:15 14:00 0.75 2,489 450 INTRM1 CASING TRIP P PJSM,TOH, f/2489'-450'MD. 14:00 14:15 0.25 450 450 INTRM1 CASING OWFF P Monitor well at HWDP, static. (Simops PJSM on L/D sources& BHA) 14:15 15:15 1.00 450 114 INTRM1 CASING BHAH P Rack back HWDP&JARS. Lay down NMFC, f/450'-114'MD. 15:15 15:45 0.50 114 114 INTRMI CASING BHAH P Remove sources as per SLB. 15:45 17:15 1.50 114 0 INTRM1 CASING BHAH P Continue laying down BHA 4 as per SLB. 17:15 17:45 0.50 0 0 INTRM1 CASING BHAH P PJSM, clear&clean rig floor. 17:45 18:00 0.25 0 0 INTRMI CASING RURD P PJSM, remove wear bushing. 18:00 18:30 0.50 0 0 INTRM1 CASING WWWH P PJSM,flush BOPE with stack washer. 18:30 19:00 0.50 0 0 INTRM1 CASING RURD P PJSM, perform dummy run w/hanger &landing joint per Vetco Rep. 19:00 20:15 1.25 0 0 INTRM1 CASING BOPE P PJSM, C/O upper rams to 9.625" solid body rams. (Simops make up Volant CRT to TD). 20:15 21:15 1.00 0 0 INTRM1 CASING BOPE P PJSM, rig up&test upper rams w/ 9.625"test joint to 250/3500 psi, 5 min each.Test annular to 250/2500 psi 5 min each. 21:15 22:30 1.25 0 0 INTRM1 CASING RURD P PJSM, rig up casing running equipment. 22:30 00:00 1.50 0 382 INTRM1 CASING PUTB P PJSM, Run 9 5/8",40#, L-80, Hyd 563 casing f/surface-382'MD. Hydroform centralizer on each joint for a total of 10. Calculated displacement 5, actual 5 bbls. 04/07/2015 Continue running intermediate casing per detail to TD @ 5715'MD. Circulate&condition mud for cement job. Cement as per plan. Pump 190 bbls of 417 bbls displacement to bump the plug. 00:00 04:15 4.25 382 2,452 INTRM1 CASING PUTB P PJSM, Run 9 5/8",40#, L-80, Hyd 563 casing f/382-2452'MD. 04:15 05:15 1.00 2,452 2,452 INTRM1 CASING CIRC P CBU at the shoe staging up the pump.5-6 bpm,200 psi, FO 42%, PU 120K, SO 115K. 05:15 08:30 3.25 2,452 2,452 INTRM1 CASING WAIT T PJSM,wait on weather to see if conditions worsen. Circulate& condition mud @ 5 bpm,240 psi, FO 41%. TT Man Down Drill held @ 07:00 hrs. 08:30 10:45 2.25 2,452 3,541 INTRMI CASING PUTB P PJSM, Run 9 5/8",40#, L-80, Hyd 563 casing f/2452'-3541' MD.A total of 78 Hydroform centralizers ran. Calculated displacement 44.8, actual 33.15 bbls. Page 11 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:15 1.50 3,541 3,541 INTRM1 CASING CIRC P CBU,staging up the pump.5-5 bpm, 240 psi, FO 45%. 12:15 14:15 2.00 3,541 4,575 INTRM1 CASING PUTB P PJSM, Run 9 5/8",40#, L-80, Hyd 563 casing f/3541'-4575' MD. 14:15 15:30 1.25 4,575 4,575 INTRM1 CASING CIRC P CBU,staging up the pump 2-4.5 bpm,250 psi, FO 42%. 15:30 17:45 2.25 4,575 5,689 INTRM1 CASING PUTB P PJSM, Run 9 5/8",40#, L-80, Hyd 563 casing f/4575'-5689'MD. 17:45 18:00 0.25 5,689 5,715 INTRM1 CASING HOSO P PJSM, make up hanger&landing joint. Land casing @ 5715'MD. Calculated displacement 33, actual 31 bbls. PU 195K, SO 110K. 18:00 22:00 4.00 5,715 5,715 INTRM1 CEMEN-CIRC P Circulate&condition mud for cement job 2-4.5 bpm, 250 psi, PU 195K, SO 130K. (Simops PJSM for pumping cement). 22:00 00:00 2.00 5,715 5,715 INTRM1 CEMEN CMNT P Line up to SLB cement unit&pump 5 bbls of H2O to test lines. Test lines 250/4000 psi,good. Batch up& pump 50 bbls of 12.0 ppg MudPush @ 3 bpm, 160 psi. Drop bottom plug. Batch up&pump 90 bbls of 15.8 ppg retarded cement @ 5.4 bpm, 260 psi. Batch&pump on the fly 110 bbls of 15.8 ppg GASBLOCK cement @ 4.6 bpm,250 psi. Drop top plug. Pump 5 bbls of 12 ppg MudPush&5 bbls of H2O @ 3 bpm, 115 psi. Swap to rig&displace with 10.1 ppg mud @ 5 bpm, 200-600 psi. Reciprocate casing 10-20'. Pump 190 bbls of 417 bbls displacement to bump the plug. 04/08/2015 WOC till 0:700 hrs, as floats did not hold. Rig down casing equip. Install pack off&test. Flush&freeze protect OA. L/D HWDP f/derrick, P/U&rack back 4"DP. Pick up handling equipment for BHA 5 00:00 01:00 1.00 5,715 5,715 INTRM1 CEMEN-CMNT P PJSM, continue cementing,displace cement to bump plug w/223 bbls,for a total of 415 bbls pumped to bump the plug. Pump @ 5 bpm, 150-720 psi. Bump the plug with 4118 strokes. Pressure up to 1250 psi& hold for 5 min. Check floats,observe floats not holding. Pressure up to 300 psi to seat plugs&shut in, holding 300 psi.Thickening time for 70 Bc,6:37.CIP 00:45 hrs. 01:00 07:00 6.00 5,715 0 INTRM1 CEMEN-WOC T WOC, hold 300 psi on plugs&wait for tail cement to reach 70 Bc. Bleed of pressure&observe no flow back. (Simops prepare to install packoff, rig up for OA flush/freeze protect,& various rig maintenance.) Table Top Rig Evacuation Drill @ 06:00 hrs. 07:00 07:30 0.50 0 0 INTRM1 CEMEN RURD P PJSM, rig down Volant CRT, lay down landing joint,&drain the stack. Page 12 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:15 0.75 0 0 INTRMI CEMEN-WWSP P PJSM, make up packoff running tool &set 12-13/16"X 9-5/8"packoff, RILDS. Inject plastic sealant, per Vetco Rep. 08:15 08:30 0.25 0 0 INTRM1 CEMEN-WWSP P PJSM, test packoff to 5000 psi for 10 min, per Vetco Rep,tested good. 08:30 11:00 2.50 0 0 INTRM1 CEMEN-FRZP P PJSM,flush OA w/163 bbls of fresh H2O @.5 bpm=600 psi, 1 bpm= 580 psi(broke over @ 650 psi), 1.5 bpm =600 psi,2 bpm=700 psi,2.5 bpm=725 psi, 3 bpm =775 psi, FCP 850 psi. Swap over to LRS& freeze protect w/119 bbls of Isotherm @.5-3 bpm, 700- 1200 psi. SIP 1200 psi. 11:00 11:30 0.50 0 0 INTRM1 CEMEN-FRZP P PJSM, rig down LRS&circulating equipment. Blow down lines. 11:30 12:00 0.50 0 0 INTRM1 CEMEN RURD P PJSM, rig up to lay down 5"HWDP &JARS. OA pressure 200 psi. @ 12:00 hrs. 12:00 13:15 1.25 0 0 INTRM1 CEMEN-PULD P PJSM, lay down 5 joints of HWDP& the JARS. 13:15 14:00 0.75 0 0 INTRM1 CEMEN RURD P PJSM, C/O handling equipment f/5" to 4". 14:00 23:30 9.50 0 0 INTRMI CEMEN-PULD P PJSM, pick up 390 joints of 4"DP& rack back in the derrick. 23:30 23:45 0.25 0 0 INTRM1 CEMEN-RURD P PJSM,clear&clean rig floor. 23:45 00:00 0.25 0 0 INTRM1 CEMEN BHAH P PJSM, pick up handling tools to rig floor for BHA 5. OA pressure 175 psi ©24:00 hrs. 04/09/2015 Make up BHA 5,shallow test SlimPulse tools©231'MD&lay down same. C/O upper rams to 3-1/2"X6" VBR's.Test BOPE w/4",4.5",&5"test joints. Install wear bushing. P/U BHA 6&TIH w/5"DP to 5596'MD. Wash down to 5618'MD,tagging up on cement. C&C mud system to test casing. Rig up to test casing. 00:00 02:00 2.00 0 46 INTRMI CEMEN BHAH P PJSM, make up BHA 5, SlimPulse tools per SLB&Baker Reps. Surface-46' MD. 02:00 02:15 0.25 46 231 INTRM1 CEMEN"TRIP P PJSM,TIH f/46'-231'MD. 02:15 02:45 0.50 231 231 INTRM1 CEMEN-DHEQ P Shallow test SlimPulse tools @ 70-100 gpm, 850-1900 psi. 02:45 03:00 0.25 231 231 INTRM1 CEMEN-TRIP P PJSM,TOH f/231'-0, C/O nozzle, TIH 0-231'MD. 03:00 03:15 0.25 231 231 INTRMI CEMEN-DHEQ P Shallow test SlimPulse tools @ 65-100 gpm, 70-325 psi. 03:15 03:45 0.50 231 231 INTRM1 CEMEN"TRIP P PJSM, TOH f/231'-0, C/O nozzle, TIH 0-231'MD. 03:45 04:30 0.75 231 231 INTRM1 CEMEN DHEQ P Shallow test SlimPulse tools @ 65-120 gpm, 550-1450 psi. 04:30 04:45 0.25 231 231 INTRMI CEMEN-TRIPP PJSM,TOH f/231'-0, remove nozzle, TIH 0-231' MD. 04:45 05:00 0.25 231 231 INTRM1 CEMEN"DHEQ P Shallow test SlimPulse tools @ 150 gpm,720 psi. good test. 05:00 05:15 0.25 231 46 INTRMI CEMEN-TRIPP PJSM,TOH f/231-46'MD. 05:15 05:45 0.50 46 0 INTRM1 CEMEN-BHAH P PJSM, lay down BHA 5 per SLB DD. Spill Drill CRT 120 sec @ 05:45 hrs. Page 13 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:15 0.50 0 0 INTRM1 CEMEN-BHAH P PJSM, clear&clean rig floor. 06:15 07:45 1.50 0 0 INTRM1 CEMEN-BOPE P PJSM, C/O upper rams to 3-1/2"X6" VBR's. 07:45 09:30 1.75 0 0 INTRM1 WHDBO RURD P PJSM, rig up to test BOPE. 09:30 15:45 6.25 0 0 INTRM1 WHDBO BOPE P PJSM,test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9&11. Test#3: Lower IBOP, CV 5,8 and 10. Test#4:4" Dart„ CV 4,6 and 7.Test#5:4" FOSV and CV 2. Test#6: HCR choke,5"FOSV, &4"kill line Demco.Test#7: Manual choke valve and HCR kill&5"Dart valve. Test#8:Annular preventer tested to 250/2500 psi. Test#9: Lower pipe rams. Test#10:Annular w/4/5"JT. Test#11 Top rams w/4/5"JT. Test #12 Lower rams w/4.5"JT.Test#13 Blind rams and CV 3.Test#14 Annular w/5"JT.Test#15 Top rams w/5"JT.Test#16 Lower rams w/5" JT.Test#17 Drawdown w/Super choke.Test#18 Drawdown w/ Manual choke.Accumulator test: system pressure=2975 psi,After closing= 1850 psi,200 psi attained after 34 sec,full pressure attained after 142 sec, Five bottle nitrogen avg=2040 psi. The BOP test witness was waived, by AOGCC Rep John Crisp. OA pressure 100 psi @ 12:00 hrs. 15:45 16:30 0.75 0 0 INTRM1 WHDBO RURD P PJSM, rig down test equipment& blow down lines. 16:30 17:15 0.75 0 0 INTRM1 WHDBO RURD P PJSM, install wear bushing w/9"ID. (Simops strap HWDP) 17:15 17:45 0.50 0 0 INTRM1 CEMEN-BHAH P PJSM, mobilize tools to the rig floor. 17:45 18:30 0.75 0 281 INTRM1 CEMEN-BHAH P PJSM, pick up BHA 6 as per SLB DD. 18:30 22:00 3.50 281 5,596 INTRM1 CEMEN-TRIP P PJSM,TIH f/281'-5596'MD, calculated displacement 48, actual 47 bbls. 22:00 22:15 0.25 5,596 5,618 INTRM1 CEMEN-COCF P Wash f/5596'-5618'MD @ 670 gpm, 1375 psi. 22:15 22:30 0.25 5,618 5,596 INTRM1 CEMEN PULD P PJSM, lay down a single. 22:30 23:30 1.00 5,596 5,596 INTRM1 CEMEN'CIRC P Circulate&condition mud system @ 500 gpm, 900 psi, FO 55%,60 rpm, Tq 6-8K, PU 115K,SO 87K, ROT 96K. 23:30 00:00 0.50 5,596 5,596 INTRM1 CEMEN-RURD P PJSM, rig up to test casing. OA pressure 60 psi. Page 14 of 70 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/10/2015 24 hr Summary Test 9-5/8"casing to 3500 psi for 30 min. Slip&cut drill line.Wait on orders. Service rig&work on MP2's. Drift,strap&tally 4.5"tubing for upper completion. Drill out float collar, shoe track,shoe, &20'of new hole. CBU&perform FIT to a EMW of 13.5 ppg. TOH 5596'-96'MD. 00:00 00:45 0.75 5,596 5,596 INTRM1 CEMEN-PRTS P PJSM,test 9-5/8"intermediate casing to 3500 psi for 30 minutes, good. 00:45 01:15 0.50 5,596 5,596 INTRM1 CEMEN'RURD P PJSM, rig down test equipment& blow down lines. Kick w/Tripping Drill CRT 95 sec @ 01:15 hrs. 01:15 02:30 1.25 5,596 5,596 INTRM1 CEMEN-SLPC P PJSM, slip&cut 52'of drill line. 02:30 03:00 0.50 5,596 5,596 INTRM1 CEMEN-SVRG P PJSM, service rig. 03:00 09:45 6.75 5,596 5,596 INTRM1 CEMEN-WAIT T Wait on orders. PJSM, drift/strap/ tally upper completion. Bring on 10.1 ppg MOBM to the pits.Work on MP2's&housekeeping. 09:45 11:15 1.50 5,596 5,596 INTRM1 CEMEN'CIRC T CBU, 540 gpm, 1200 psi,60 rpm,Tq 7-9K, PU 101K, SO 96K, ROT 100K. 11:15 12:30 1.25 5,596 5,596 INTRM1 CEMEN-WAIT T Wait on orders. PJSM, drift/strap/ tally upper completion.Work on MP2's&housekeeping. 12:30 12:45 0.25 5,596 5,632 INTRM1 CEMEN COCF P PJSM,clean out cement to float collar 5596'-5632'MD,450 gpm, 650psi,60 rpm,Tq 10K,WOB 11K, PU 101K, SO 96K, ROT 100K. 12:45 15:30 2.75 5,632 5,725 INTRM1 CEMEN'DRLG P PJSM,drill out float collar,shoe track&shoe, 5632'-5725'MD,450 gpm,650psi, 60 rpm, Tq 10K,WOB 11K, PU 110K, SO 97K, ROT 107K. 15:30 15:45 0.25 5,725 5,745 INTRM1 CEMEN DDRL P PJSM,drill 20'new hole,5725'-5745' MD, 390 gpm, 650psi,60 rpm, Tq 10K,WOB 11K, PU 110K, SO 97K, ROT 107K. 15:45 16:45 1.00 5,745 5,596 INTRM1 CEMEN-CIRCP CBU 2X @ 600 gpm, 1400 psi, 100 rpm, Tq 8-9K. Racking back a stand in the derrick after first BU f/ 5745'-5596. 16:45 17:30 0.75 5,596 5,596 INTRM1 CEMEN-FIT P PJSM, rig up&perform FIT to 13.5 ppg EMW. Pressured up to 700 psi &shut in for 10 minutes. 17:30 18:00 0.50 5,596 5,596 PROD1 DRILL OWFF P Monitor well, static. (Blow down TD) 18:00 20:30 2.50 5,596 4,748 PROD1 DRILL PMPO P PJSM, pump out of the hole f/ 5596-4748'MD,4 bpm, 300 psi, PU 125K, SO 97. Drop 2"OD rabbit (stand#68)prior to TOH. 20:30 23:30 3.00 4,748 315 PROD1 DRILL TRIP P PJSM,TOH f/4748'-315'MD. Kick w/Tripping Drill CRT 82 sec @ 22:00 hrs. 23:30 23:45 0.25 315 315 PROD1 DRILL OWFF P Monitor well, static. 23:45 00:00 0.25 315 96 PROD1 DRILL PULD P PJSM, lay down 5 joints of HWDP& the jars. OA pressure 0 psi©24:00 hrs. Page 15 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/11/2015 24hrSummary Finish laying down BHA 6. C/O handling equipment f/5"to 4". Repair pipe skate. Make up BHA 7&TIH to 5745'MD. CBU&displace LSND to 10.1ppg MOBM system. Directional drill 6-3/4"A2 lateral section per plan f/5745'-6234'MD, 3925'TVD. 00:00 00:30 0.50 96 0 PROD1 DRILL BHAH P PJSM, finish laying down BHA 6. 00:30 01:00 0.50 0 0 PROD1 DRILL BHAH P PJSM, clear&clean rig floor. 01:00 04:15 3.25 0 0 PROD1 DRILL RURD P PJSM, C/O handling equipment f/5" to 4". C/O TD saver sub,TD bell guide,TD grabbers, &head on Iron Ruff Neck. Pre-clean under shakers for MOBM. 04:15 05:00 0.75 0 22 PROD1 DRILL BHAH P PJSM, pick up BHA 7 make up bit& PowerDrive 0-22'. 05:00 05:30 0.50 22 22 PROD1 DRILL SVRG P PJSM,service rig. 05:30 07:00 1.50 22 22 PROD1 DRILL RGRP T PJSM, repair pipe skate. 07:00 08:45 1.75 22 374 PROD1 DRILL BHAH P PJSM, pick up BHA 7,f/22'-374' MD. 08:45 09:45 1.00 374 1,791 PROD1 DRILL TRIP P PJSM,TIH from 374'-1791' MD. 09:45 10:30 0.75 1,791 1,791 PROD1 DRILL DHEQ P Shallow test MWD @ 220 gpm, 1000 psi.Tested good. 10:30 12:15 1.75 1,791 5,667 PROD1 DRILL TRIP P PJSM,TIH from 1791'-5667'MD. Calculated displacement 38.1, actual 34.5 bbls. OA pressure 0 psi. 12:15 12:30 0.25 5,667 5,745 PROD1 DRILL REAM P Wash down 5667'-5745'MD,250 gpm, 1700 psi, 75 rpm, Tq 5-6K, FO 45%. 12:30 14:30 2.00 5,745 5,745 PROD1 DRILL CIRC P CBU @ 270 gpm, 1800 psi,80 rpm, Tq 5K, PU 90K, SO 84K, ROT 86k. 14:30 16:30 2.00 5,745 5,745 PROD1 DRILL DISP P PJSM, displace LSND w/10.1 ppg FazPro MOBM system @ 270 gpm, 2250 psi, 80 rpm,Tq 2-4K, PU 95K, SO 77K, ROT 85K. Pump 35 bbl Surfactant spacer pill,then displace w/407 bbls of MOBM. SPR's @ 5738'MD, 3921'TVD, MW 10.1 ppg, 16:00 hrs. #1 ©30=575, @ 40=880 #2 @ 30=580, ©40=875 16:30 16:45 0.25 5,745 5,745 PROD1 DRILL CIRC P Establish parmeters&down link, 270 gpm,2250 psi, 80 rpm, Tq 2-4K, PU 95K, SO 77K, ROT 85K. 16:45 18:00 1.25 5,745 5,814 PROD1 DRILL DDRL P DDrill f/5745-5814'MD, 3924'TVD, ADT 1.28, BIT 1.28,JARS 134.26, PU 95K, SO 77K, ROT 85K,TQ on 1-4K, off 2-4K, ECD 10.6, FO 42%, WOB 1-4K, 80 rpm, 270 gpm, 2275 psi. Max Gas 37 Page 16 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 5,814 6,234 PROD1 DRILL DDRL P DDrill f/5814'-6234' MD,3925'TVD, ADT 4.27, BIT 5.55, JARS 138.53, PU 97K, SO 74K, ROT 84K, TQ on 3-4K,off 2-3K, ECD 10.77, FO 42%, WOB 1-4K, 80 rpm,270 gpm,2300 psi. Max Gas 68 SPR's @ 6234'MD, 3925'TVD, MW 10.1 ppg,23:45 hrs. #1 @ 30=560, @ 40=910 #2©30=560, @ 40=860 OA pressure 0 psi Kick Drilling CRT 105 sec @ 23:30 hrs. 34/12/2015 Directional drill 6-3/4"A2 lateral section per plan f/6234'-8313'MD, 3962'TVD. 00:00 06:00 6.00 6,234 6,788 PROD1 DRILL DDRL P DDrill f/6234'-6788'MD,3956'TVD, ADT 4.77, BIT 10.32,JARS 143.30, PU 105K, SO 70K, ROT 88K,TQ on 4K,off 2K, ECD 11.01, FO 42%, WOB 3-5K, 140 rpm, 270 gpm,2400 psi. Max Gas 69 SPR's @ 6706'MD, 3947'TVD, MW 10.1 ppg, 06:00 hrs. #1 @ 20=390, @ 30=600 #2 @ 20=400, @ 30=625 OA pressure 0 psi Kick Drilling CRT 60 sec @ 06:00 hrs. 06:00 12:00 6.00 6,788 7,330 PROD1 DRILL DDRL P DDrill f/6788'-7330' MD,3962'TVD, ADT 4.56, BIT 14.88,JARS 147.86, PU 105K, SO 68K, ROT 83K,TQ on 4K,off 3K, ECD 11.16, FO 40%, WOB 3-5K, 140 rpm, 270 gpm, 2525 psi. Max Gas 73 SPR's©7325'MD, 3962'TVD, MW 10.1 ppg, 12:00 hrs. #1 @ 20=390, @ 30=630 #2 @ 20=380, @ 30=620 12:00 18:00 6.00 7,330 7,899 PROD1 DRILL DDRL P DDrill f/7330'-7899' MD, 3956'TVD, ADT 4.33, BIT 19.21,JARS 152.19, PU 115K, SO 52K, ROT 85K,TQ on 2-5K,off 2-3K, ECD 11.38, FO 41%, WOB 2-4K, 140 rpm,270 gpm, 2550 psi. Max Gas 66 SPR's @ 7838'MD, 3955'TVD, MW 10.2 ppg, 18:35 hrs. #1 @ 20=410, @ 30=670 #2 @ 20=410, @ 30=670 __ Page 17 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,899 8,313 PROD1 DRILL DDRL P DDrill f/7899'-8313'MD,3962'TVD, ADT 4.19, BIT 23.4,JARS 156.38, PU 120K, SO 56K, ROT 84K,TQ on 4-5K, off 3-4K, ECD 11.36, FO 41%, WOB 3-5K, 140 rpm,270 gpm,2675 psi. Max Gas 63 SPR's @ 8311'MD, 3962'TVD, MW 10.1 ppg,23:45 hrs. #1 @ 20=380, @ 30=630 #2 @ 20=390, @ 30=640 OA pressure 0 psi. 34/13/2015 Directional drill 6-3/4"A2 lateral section per plan f/8313'-9922'MD, 3978'TVD. 00:00 06:00 6.00 8,313 8,692 PROD1 DRILL DDRL P DDrill f/8313'-8692'MD,3971'TVD, ADT 4.62, BIT 28.02, JARS 161.0, PU 115K, SO 63K, ROT 85K,TQ on 5K, off 4K, ECD 11.45, FO 40%, WOB 5-14K, 140 rpm,270 gpm, 2700 psi. Max Gas 75 SPR's @ 8692'MD, 3971'TVD, MW 10.1 ppg, 05:30 hrs. #1 @ 20=460, @ 30=800 #2 @ 20=440, @ 30=720 Spill Drill CRT 120 sec @ 04:00 hrs. 06:00 12:00 6.00 8,692 9,126 PROD1 DRILL DDRL P DDrill f/8692'-9126' MD, 3976'TVD, ADT 3.53, BIT 32.18,JARS 165.16, PU 120K, SO 62K, ROT 86K,TQ on6K, off 4K, ECD 11.68, FO 40%, WOB 3-14K, 140 rpm,270 gpm, 2900 psi. Max Gas 63 SPR's @ 9112'MD, 3976'TVD, MW 10.1+ppg, 11:30 hrs. #1 @ 20=600, @ 30=830 #2 @ 20=560, @ 30=780 12:00 18:00 6.00 9,126 9,524 PROD1 DRILL DDRL P DDrill f/9126'-9524' MD, 3975'TVD, ADT 3.84, BIT 36.02, JARS 169.0, PU 115K, SO 69K, ROT 82K,TQ on 5K, off 3-4K, ECD 11.65, FO 40%, WOB 4-10K, 140 rpm,270 gpm, 3050 psi. Max Gas 63 18:00 00:00 6.00 9,524 9,922 PROD1 DRILL DDRL P DDrill f/9524'-9922' MD, 3978'TVD, ADT 4.60, BIT 40.62,JARS 173.6, PU 118K, SO 59K, ROT 84K,TQ on 5-6K, off 3-4K, ECD 11.61, FO 41%, WOB 4-6K, 140 rpm,270 gpm, 3010 psi. Max Gas 65 SPR's @ 9920'MD, 3977'TVD, MW 10.1 ppg, 23:45 hrs. #1 @ 20=520, @ 30=810 #2 @ 20=530, @ 30=810 Spill Drill CRT 100 sec @ 23:15 hrs. 34/14/2015 Directional drill 6-3/4"A2 lateral section per plan f/9922'-11343'MD,3976'TVD. Page 18 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 9,922 10,253 PROD1 DRILL DDRL P DDrill f/9922'-10253'MD, 3978'TVD, ADT 4.19, BIT 44.81,JARS 177.79, PU 115K, SO 63K, ROT 85K,TQ on 6K,off 4K, ECD 11.70, FO 41%, WOB 4-10K, 140 rpm,270 gpm, 3100 psi. Max Gas 69 Fire Drill CRT 120 sec @ 03:00 hrs 06:00 12:00 6.00 10,253 10,522 PROD1 DRILL DDRL P DDrill f/10253'-10522'MD,3980' TVD,ADT 4.71, BIT 49.52,JARS 182.50, PU 110K, SO 60K, ROT 85K,TQ on 6K, off 4K, ECD 11.77, FO 40%,WOB 3-10K, 140 rpm,270 gpm,3150 psi. Max Gas 69 SPR's @ 10396'MD,3978'TVD, MW 10.1 ppg, 09:00 hrs. #1 @ 20=560, @ 30=825 #2 @ 20=550, @ 30=800 12:00 18:00 6.00 10,522 10,969 PROD1 DRILL DDRL P DDrill f/10522'-10969'MD, 3977' TVD,ADT 4.39, BIT 53.91,JARS 186.89, PU 118K, SO 48K, ROT 82K, TQ on 6-8K, off 4-6K, ECD 12.0, FO 42%,WOB 3-6K, 140 rpm, 275 gpm,3300 psi. Max Gas 42 SPR's @ 10965'MD, 3978'TVD, MW 10.1 ppg, 17:15 hrs. #1 @ 20=640, @ 30=910 #2 @ 20=680, @ 30=920 18:00 00:00 6.00 10,969 11,343 PROD1 DRILL DDRL P DDrill f/10969'-11343'MD, 3976' TVD,ADT 4.49, BIT 58.40,JARS 191.38, PU 115K, SO 54K, ROT 82K, TQ on 6K, off 4-5K, ECD 11.91, FO 41%,WOB 1-4K, 140 rpm, 275 gpm, 3450 psi. Max Gas 200 SPR's @ 11343'MD,3976'TVD, MW 10.1 ppg, 23:45 hrs. #1 @ 20=600, @ 30=900 #2 @ 20=620, @ 30=900 OA=160 psi 34/15/2015 Directional drill 6-3/4"A2 lateral section per plan f/11343'-12188' MD, 3982'TVD. Circ open hole vol. Backream to 12007'MD and RIH to 12188'MD. OWFF. BROOH f/12188'MD t/7550'MD 00:00 06:00 6.00 11,343 11,627 PROD1 DRILL DDRL P DDrill f/11343'-11627'MD, 3978' TVD,ADT 4.39, BIT 62.79,JARS 195.77, PU 112K, SO 55K, ROT 85K, TQ on 6K,off 4K, ECD 12.05, FO 40%,WOB 3-10K, 140 rpm, 275 gpm, 3425 psi. Max Gas 275 Kick w/drilling drill-CRT=120 sec Page 19 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 11,627 11,627 PROD1 DRILL DDRL P DDrill f/11627'-12090'MD, 3976' TVD,ADT 4.56, BIT 67.35,JARS 200.33, PU 109K, SO 55K, ROT 80K,TQ on 6K, off 5K, ECD 12.05, FO 40%,WOB 4-10K, 140 rpm,275 gpm, 3500 psi. Max Gas 289 SPR's @ 11816'MD, 3978'TVD, MW 10.1 ppg, 08:00 hrs. #1 @ 20=610, ©30=900 #2 @ 20=660, @ 30=910 OA=185 psi 12:00 13:00 1.00 11,627 12,188 PROD1 DRILL DDRL P DDrill f/12090'-12188'MD, 3982' TVD,ADT.87, BIT 68.22, JARS 201.20, PU 118K, SO 55K, ROT 82K,TQ on 6-7K, off 5-6K, ECD 12.19, FO 42%,WOB 4-5K, 140 rpm,275 gpm, 3450 psi. Max Gas 275 13:00 14:30 1.50 12,188 12,188 PROD1 CASING CIRC P Circ open hole volume.275 gpm=3450 psi. 140 rpm. Tq 4-6K PU 118K, SO 55K, ROT 82K SPR's @ 12188'MD,3981'TVD, MW 10.1 ppg, 13:30 hrs. #1 ©20=670, @ 30=960 #2©20=700, @ 30=960 14:30 15:00 0.50 12,188 12,188 PROD1 CASING BKRM P Back ream f/12188'MD t/12007'MD. Wash back to 12188'MD.3 bpm= 960 psi. SO 55K. 15:00 15:15 0.25 12,188 12,188 PROD1 CASING OWFF P Monitor well. Static. 15:15 00:00 8.75 12,188 7,550 PROD1 CASING BKRM P BROOH f/12188'MD t/7550'MD.275 gpm,3450 psi, 140 rpm,tq 4-5K, PU 118K, SO 55K, ROT 82K. Kick w/tripping drill. CRT=75 sec OA=162 psi 34/16/2015 BROOH to shoe©5715'MD. CBU. Open circ sub. CBU x 4 @ 630 gpm. Close circ sub.TIH to td @ 12188' MD. CBU. Displace to SFOBM. OWFF. Pump out of hole to 8789' MD 00:00 02:45 2.75 7,550 5,715 PROD1 CASING BKRM P Continue to back ream out of the hole.64 spm,275 gpm,2700psi, 140 rpm, TQ=4k, ECD=10.77 ppg, OA=130 psi.KWTD=CRT 1.00 min. 02:45 03:45 1.00 5,715 5,715 PROD1 CASING CIRC P CBU @ 5715'MD. Inside 9.625" casing.64 spm, 275 gpm,2425 psi, 80 rpm,TQ=2k, CDE=10.69 ppg. Shakers clean. Page 20 of 70 Time Logs 41111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 04:00 0.25 5,715 5,715 PROD1 CASING OWFF P Observe well for flow. Static. Function test BOPE. upper and lower pipe rams, annular. 04:00 04:30 0.50 5,715 5,900 PROD1 CASING TRIP P Trip in two stands. Set circulating sub @ 5712' MD. Drop 1.75"steel opening ball. Pump @ 2 bpm,400 psi, place ball on seat, Shear out with 1700 psi. 04:30 06:00 1.50 5,900 5,900 PROD1 CASING CIRC P Rotate and reciprocate. CBU.80 rpm,650 gpm,3700 psi, BU 4x's. 1st bottoms up brought 200% excess compared to drilling cuttings load. the last three BU cycles had minimal cuttings. 06:00 06:30 0.50 5,900 5,667 PROD1 CASING BKRM P BROOH f/5900' MD t/5667'MD. 500 gpm, 2500 psi 06:30 07:00 0.50 5,667 5,667 PROD1 CASING OWFF P Monitor well. Static. Service TD. 07:00 07:15 0.25 5,667 5,667 PROD1 CASING CIRC P Drop 1.75"steel closing ball.Pump @ 2bpm,400 psi, place ball on seat, Close with 1700 psi. 07:15 12:00 4.75 5,667 11,061 PROD1 CASING WPRT P RIH on elevators f/5667'MD t/11061' MD. Fill pipe every 20 stds. Calc disp=29.7 bbls.Act disp=28.5 bbls. OA=130 psi 12:00 13:15 1.25 11,061 12,102 PROD1 CASING WPRT P Con't to RIH on elevators f/11061' MD t/12102'MD. Fill pipe every 20 stds. 13:15 14:45 1.50 12,102 12,188 PROD1 CASING CIRC P Ream down f/12102' MD t/12188' MD. CBU.265 gpm, 3500 psi, 140 rpm,tq 5-7K, PU 115K, SO 52K, ROT 76K. 14:45 17:30 2.75 12,188 12,188 PROD1 CASING DISP P Displace well from 10.1 ppg Faz-Pro OBM to 10.3 ppg SFOBM.250 gpm, 3500 psi, 80 rpm.tq 5-6K. Reduce rate to 200 gpm/3000 psi as SFOBM reaches bit to control ECDs to less than 13.3 ppg. 17:30 17:45 0.25 12,188 12,188 PROD1 CASING OWFF P OWFF. Static. 17:45 18:00 0.25 12,188 12,180 PROD1 CASING CIRC P Establish SPR's. Take on remaining SFOBM. SPR's @ 12180'MD, 3981'TVD, MW 10.3 ppg, 17:45 hrs. #1 @ 10=1260, @ 20=1780 #2 @ 10=1280, @ 20=1800 18:00 00:00 6.00 12,180 8,789 PROD1 CASING PMPO P Pump out of hole from 12180' MD to 8789' MD. 3 bpm,2250 psi. PU 98K, SO 53K. Calc disp=19 bbls Act disp=29 bbls.OA=135 psi 74/17/2015 Con't to pump out of hole to shoe. OWFF. Pump out of hole to 4248'MD. OWFF. POH to 1321'MD.OWFF. Mix 15 bbls SFOBM. POH to HWDP. OWFF. Lay down BHA. Service circ sub. Clear floor. Change out saver sub and handling equp.to 5". Flush stack. Rig up to run 4 1/2"lower completion. Run 4'/z"slotted,blank liner to 252'MD Page 21 of 70 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:45 4.75 8,789 5,667 PROD1 CASING PMPO P PJSM. Continue to pump out of the hole from 8789'MD to the shoe, 5667' MD. 3 bpm, 1600 psi. 04:45 05:15 0.50 5,667 5,667 PROD1 CASING OWFF P OWFF. Dropped 1/2"in 30 mins. Static. 05:15 07:30 2.25 5,667 4,248 PROD1 CASING PMPO P Continue to pump out of the hole from 5667'MD to 4248'MD. 3 bpm, 1200 psi. Calc disp=26.4 bbls Act disp=32.5 07:30 08:00 0.50 4,248 4,248 PROD1 CASING OWFF P Blow down TD. OWFF. Static 08:00 11:30 3.50 4,248 1,321 PROD1 CASING TRIP P POH from 4248'MD to 1321'MD. Calc disp=16.2 Act disp=21.4 bbls 11:30 12:00 0.50 1,321 1,321 PROD1 CASING OWFF P OWFF. Static. Mix 15 bbls SFOBM in pit#5 OA=150 psi 12:00 13:30 1.50 1,321 1,321 PROD1 CASING COND T Con't to mix 15 bbls SFOBM in pit #5. 13:30 14:45 1.25 1,321 347 PROD1 CASING TRIP P POH from 1321'MD to 347'MD. 14:45 15:15 0.50 347 347 PROD1 CASING OWFF P OWFF. Static 15:15 17:00 1.75 347 0 PROD1 CASING BHAH P Service break circ sub. Lay down BHA as per SLB rep. Calc disp=26.6 bbls Act disp=34.35 17:00 18:00 1.00 0 0 PROD1 CASING BHAH P Clean and clear rig floor. Remove circ sub activation balls. Torque service break on circ sub. 18:00 21:00 3.00 0 0 COMPZ CASING RURD P PJSM-Change out TD saver sub. Rig up 5"handling equip. 21:00 21:45 0.75 0 0 COMPZ CASING WWWH P PU stack washing tool. Flush BOP stack. 21:45 23:15 1.50 0 0 COMPZ CASING RURD P Rig up casing equip.to run lower completion 23:15 00:00 0.75 0 252 COMPZ CASING PUTB P PU 4 1/2"IBTM, 11.6#, L-80, slotted/blank liner to 252'MD. 04/18/2015 PU 4'/z'slotted/blank liner with three swell packers,two Trecerco cartridge tools. PU SlimPulse MWD tools and orient to liner hanger. RIH whiner on DP to 12156'MD installing super sliders on first 765 jts. and shallow test MWD @ 7400'MD. Orient hanger.Drop ball. Set hanger and liner top packer.Test annulus to 2500 psi.. Pull seals from SBE. CBU. OWFF. 00:00 06:45 6.75 252 6,921 COMPZ CASING PUTB P PU 4 1/2"IBTM, 11.6#, L-80, slotted/blank liner from 252'MD to 6921'MD. PU 80K SO 62K 06:45 08:00 1.25 6,921 6,921 COMPZ CASING BHAH P Rig down csg. equip, clear floor. Pick up Baker slim hole handling equip. 08:00 10:00 2.00 6,921 6,921 COMPZ CASING BHAH P MU super slim inner string MWD, SBE, MLZXP liner hanger packer. 10:00 11:30 1.50 6,921 6,921 COMPZ CASING OTHR P Mix and set pal mix. Clear rig floor. PU WATT super sliders and installation equip. Lay down slim hole handling equip. Rig up WWT equip. 1 Page 22 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 6,921 7,026 COMPZ CASING RUNL P RIH w/slotted liner on 5"DP f/6921' MD t/7026'MD.. Install superslider on each jt. Pump through running tool and MWD.68 gpm, 300 psi. Calc disp=29.1 bbls Act Disp=28.4 bbls. 12:00 12:45 0.75 7,026 7,400 COMPZ CASING RUNL P RIH w/slotted liner on 5"DP f/7026' MD t/7400'MD.. Install superslider on each jt. 12:45 13:15 0.50 7,400 7,400 COMPZ CASING DHEQ P Shallow hole test MWD. 80 gpm, 390 psi, 17%FO.Tested good. 13:15 20:00 6.75 7,400 12,156 COMPZ CASING RUNL P RIH w/slotted liner on 5"DP f/7400' MD t112156'MD.. Install superslider on each jt.for first 75 jts. Establish circ. Calc disp=43.1 bbls Act disp=42.35 bbls 20:00 21:00 1.00 12,156 12,156 COMPZ CASING HOSO P Break circ 80 gpm, 750 psi, 16% FO. Stage rate up to 113 gpm, 1100 psi,24%FO. Orient MLZXP hanger/packer profile to 12.4°left of high side. 21:00 22:15 1.25 12,156 12,156 COMPZ CASING PACK P Drop 1.75"ball. Pump ball down @ 113 gpm,1100 psi,24% FO. Slow rate to 65 gpm, 700 psi @ 613 stks to seat ball. Ball on seat @ 748 stks.w/800 psi. Pressure up to 1900 psi to set hanger. Slack off to 50K w/ rotating to set packer. Pressure up to 2700 psi/1 min. Pressure up to 3000 psi/1 min. Pressure up to 3300 psi/1 min. Pressure up to 4000 psi. Bleed pressure off and pick up to verify release of running tool. TOL=5235'MD 22:15 22:45 0.50 12,156 5,161 COMPZ CASING PRTS P Rig up and test annulus. Pumping away @ 2 bpm/1200 psi. Pick up and expose dog sub. Slack off 60K. Confirm w/rotation.Test annulus to 2500 psi/10 mins. Bleed off pressure. Pull out of liner top w/ pumping 1 bpm. 22:45 23:15 0.50 5,161 5,161 COMPZ WELLPF CIRC P CBU. 9 bpm, 1100 psi,54%FO 23:15 23:30 0.25 5,161 5,129 COMPZ WELLPF RURD P Stand back one stand of DP. Rig down test equip. Blow down cmt. line. PU 113K SO 95K 23:30 00:00 0.50 5,129 5,129 COMPZ WELLPFOWFF P OWFF. Dropped 1"in 30 min. Static OA=175 psi 34/19/2015 POH to 81'MD.OWFF. Lay down running tool and MWD. Clear floor. Slip and cut drlg line. MU whipstock/milling assy. RIH to 1550'MD. Shallow test MWD. RIH to 2202'MD. Mad pass f/2202'MD t/2219' MD.Add mud to pit#5 to regain MWD signal. Mad pass f/2219'MD t/2312'MD. RIH t/5212'MD.Establish parameters. Survey whipstock orientation. Latch MLZXP anchor. Circ to clear air from mud system. 00:00 06:30 6.50 5,129 81 COMPZ WELLPF TRIP P POOH f/5129'MD t/81'MD. Calc disp=41.2 bbls Act disp=48.3 bbls 06:30 07:00 0.50 81 81 COMPZ WELLPF OWFF P OWFF. Static _. _____Page 23 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:15 1.25 81 0 COMPZ WELLPF BHAH P Lay down liner running tool and slim hole MWD 08:15 08:45 0.50 0 0 COMPZ WELLPF BHAH P Clean and clear rig floor 08:45 10:15 1.50 0 0 COMPZ WELLPF SLPC P Slip and cut 65'drilling line. Service rig. 10:15 12:30 2.25 0 0 PROD2 WHPST BHAH P Make up Baker 8 1/2"milling assy. Scribe and orient MWD. Stand back in derrick. 12:30 14:30 2.00 0 146 PROD2 WHPST BHAH P Make up Baker whipstock assy. Orient seal assy.Assemble mill assy to whipstock assy. 14:30 16:30 2.00 146 1,550 PROD2 WHPST TRIP P RIH w/whipstock/mill assy to 1550' MD 16:30 16:45 0.25 1,550 1,550 PROD2 WHPST DHEQ P Fill pipe and shallow test MWD.352 gpm,600 psi,49%FO. 16:45 17:30 0.75 1,550 2,202 PROD2 WHPST TRIP P RIH f/1550'MD t/2202'MD. 17:30 17:45 0.25 2,202 2,219 PROD2 WHPST DLOG P Mad pass f/2202'MD t/2219' MD as per geologist. MWD sensor depth at start of mad pass @ 2090'MD,2071' TVD 17:45 18:30 0.75 2,219 2,219 PROD2 WHPST DLOG T Add mud to pit#5 to regain MWD signal 18:30 19:15 0.75 2,219 2,312 PROD2 WHPST DLOG P Con't to mad pass(/2219'MD t/2312' MD as per geologist. 200 fph,350 gpm,600 psi, 55%FO.Tie in K-15 marker @ 2140'MD, 2120'TVD 19:15 23:00 3.75 2,312 5,212 PROD2 WHPST TRIP P RIH f/2312'MD t/5212'MD. Fill pipe every 10 stds. PU 103K SO 87K. Cal disp=41.84 bblos Act disp=42.1 bbls 23:00 23:45 0.75 5,212 5,212 PROD2 WHPST CIRC P Break circ. Establish parameters. 350 gpm, 1225 psi,50%FO. 500 gpm, 1750 psi, 54%FO.Whipstock laying 31.5° R of highside. 23:45 00:00 0.25 5,212 5,247 PROD2 WHPST CIRC P RIH and latch MLZXP anchor on depth @ 5247'MD. Circ to clear air from mud system. 34/20/2015 Obtain final whipstock orientation. Shear whipstock bolt.Test MLZXP seals.Prep pits for displacement. Displace 10.3ppg SFOBM w/10.1ppg Faze-Pro MOBM.MiII window f/5191'MD t/5208'MD and 20'new hole to 5229' MD.Work mills through window. Pump hi-vis sweep. Perform FIT to 13.5 ppg EMW. OWFF. Pump out of hole to 4195'MD. POOH on elevators to 214'MD. OWFF. Lay down milling assy. 00:00 01:30 1.50 5,247 5,186 PROD2 WHPST DLOG P Obtain MWD survey. Final orientation of whipstock 7.5° R of high side. Confirm placement w/rig engineer.Shear off of whipstock w/ 40K down weight. PU 4' 01:30 02:00 0.50 5,186 5,186 PROD2 WHPST PRTS P Test MLZXP seal assy to 650 psi/10 min. Chart test.Sim-ops-Conduct PJSM for displaceing well to 10.1 ppg Faze-Pro OBM. 02:00 03:15 1.25 5,186 5,186 PROD2 WHPST RURD P Prep pits for displacement. 03:15 04:45 1.50 5,186 5,186 PROD2 WHPST DISP P Displace well from 10.3 ppg SFOBM to 10.1 ppg Faze-Pro MOBM. _ - Page 24 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 11:00 6.25 5,186 5,208 PROD2 WHPST MILL P Obtain SPR's and milling parameters. Mill window f/5191'MD t/5208'MD. PU 100K, SO 93K, ROT 95K, 560 gpm, 1600 psi,WOB 9K, 90-110 rpm,5K tq. SPR's @ 5186'MD, 3846'TVD, MW 10.1 ppg,05:00 hrs. #1 @ 30=210, @ 40=240 #2 @ 30=205, @ 40=245 11:00 13:30 2.50 5,208 5,229 PROD2 WHPST DDRL P DDrill new hole f/5208't/5229'MD 3855'TVD. ADT 2.5, PU 100K, SO 93K, ROT 95K, TQ 3-4K,,, FO 54%, WOB 4-5K, 110 rpm, 560 gpm, 1600 psi. Max Gas 92 13:30 14:00 0.50 5,229 5,229 PROD2 WHPST REAM P Work milling assy.through window while pumping and rotating x2.Work assy.through window w/o rotation. No excess drag observed. 14:00 15:00 1.00 5,229 5,229 PROD2 WHPST CIRC P Pump 25 bbls hi-vis sweep.Circ till even mud wt. in/out. 15:00 15:30 0.50 5,229 5,155 PROD2 WHPST RURD P Stand back one stand of DP. Rig up to perform FIT. 15:30 15:45 0.25 5,155 5,155 PROD2 WHPST FIT P Perform FIT to 13.5 ppg EMI/V. 680 psi surface pressure. 10.1 ppg mud wt.3855'TVD. 15:45 16:00 0.25 5,155 5,155 PROD2 WHPST RURD P Rig down test equip. Blow down cmt and kill lines 16:00 16:45 0.75 5,155 5,155 PROD2 WHPST OWFF P OWFF. Static. Sim-ops-PJSM for pump out of hole and TOOH. 16:45 17:00 0.25 5,155 5,124 PROD2 WHPST CIRC P Lay down single jt. DP. Obtain SPR's SPR's @ 5124'MD, 3831'TVD, MW 10.1 ppg, 17:00 hrs. #1 @ 30=160, ©40=220 #2 @ 30=180, @ 40=210 17:00 19:00 2.00 5,124 4,195 PROD2 WHPST PMPO P Pump out of hole f/5124'MD t/4195' MD. 150 gpm,225 psi. Calc fill=7.7 bbls Act fill=11.47 bbls 19:00 22:45 3.75 4,195 214 PROD2 WHPST TRIP P POOH on elevators f/4195'MD t/214' MD. 22:45 23:00 0.25 214 214 PROD2 WHPST OWFF P Monitor well. Static. 23:00 00:00 1.00 214 0 PROD2 WHPST BHAH P Lay down milling BHA as per SLB and Baker reps. Starter mill @ 1/8" out of gauge. Upper mill @ full gauge. Calc disp=35.42 bbls Act disp=41.65 bbls. 34/21/2015 Flush BOP's. Change out 5"handling equip to 4".MU clean out BHA. RIH to 5174'MD. Orient motor to high side and exit window. DDrlg f/5229'MD t/5361'MD 3866'TVD. CBU. Pump out of hole to 4890' MD. POOH to 448'MD.OWFF. Lay down clean out BHA. PU and surface test FDJ tool. 00:00 01:00 1.00 0 0 PROD2 WHPST BHAH P Clear and clean rig floor. Lay down milling tools. Page 25 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:15 1.25 0 0 PROD2 WHPST WVVWH P Flush BOPE. Function annular, upper and lower VBR's and blind rams.650 gpm. Rotate @ 10 rpm 02:15 04:45 2.50 0 0 PROD2 WHPST RURD P Change out TD handling equip from 5"to 4". 04:45 07:30 2.75 0 385 PROD2 WHPST BHAH P Make up clean out BHA as per SLB rep. 07:30 08:00 0.50 385 1,485 PROD2 WHPST TRIP P RIH f/385'MD t/1485'MD 08:00 08:30 0.50 1,485 1,485 PROD2 WHPST DHEQ P Fill pipe. Shallow hole pulse test MWD. 08:30 10:15 1.75 1,485 5,174 PROD2 WHPST TRIP P RIH f/1485 t/5174'MD. Fill pipe every 20 stds. 10:15 10:45 0.50 5,174 5,208 PROD2 WHPST CIRC P Fill pipe. Obtain SPR's. Orient motor to high side. Exit through window. SPR's @ 5175'MD, 3842'TVD, MW 10.2 ppg, 10:15 hrs. #1 @ 20=480, ©30=760 #2 @ 20=490, ©30=740 10:45 12:00 1.25 5,208 5,286 PROD2 DRILL DDRL P DDrill f/5208 MD't/5286'MD, 3870' TVD,ADT.94,AST.94 BIT.94, JARS.94, PU 90K, SO 78K,, , FO 40%,WOB 10-13K, 220 gpm, 1875 psi. Max Gas 101 12:00 13:00 1.00 5,286 5,361 PROD2 DRILL DDRL P DDrill f/5286 MD't/5361'MD, 3866' TVD,ADT.75,ART.58 AST..17 BIT 1.69, JARS 1.69, PU 92K, SO 75K„ ROT 85K Tq on 3K,Tq off 2K FO 40%,WOB 10K, 35 rpm 220 gpm, 1975 psi. Max Gas 128 13:00 14:30 1.50 5,361 5,361 PROD2 DRILL CIRC P Survey©5361' MD. CBU.220 gpm, 1880 psi, 30 rpm,Tq 2.5K, FO 40%. Obtain SPR's Blow down TD. SPR's @ 5360'MD, 3866'TVD, MW 10.2 ppg, 14:25 hrs. #1 @ 20=580, @ 30=720 #2 @ 20=480, @ 30=700 14:30 15:15 0.75 5,361 5,361 PROD2 DRILL OWFF P OWFF. Static. 15:15 16:15 1.00 5,361 4,890 PROD2 DRILL PMPO P Pump out of hole f/5361'MD t/4890' MD. 150 gpm, 950 psi, FO 31%. Calc disp=2.8 bbls Act disp=5.09 Blow down TD 16:15 20:15 4.00 4,890 448 PROD2 DRILL TRIP P POOH on elevators f/4890'MD t/448' MD. 20:15 20:45 0.50 448 448 PROD2 DRILL OWFF P OWFF.Static. 20:45 22:15 1.50 448 0 PROD2 DRILL BHAH P Lay down clean out BHA as per SLB rep. Calc disp=31.37 bbls Act disp=36.38 bbls Page 26 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 0 0 PROD2 DRILL BHAH P Clean and clear rig floor. 22:45 00:00 1.25 0 8 PROD2 DRILL DHEQ P Make up and surface test FDJ tool. Tool actuated @ 520 gpm,750 psi. 04/22/2015 Make up MWD. RIH to 1559' MD.Test FDJ/MWD compatibility. POOH. Lay do MWD and FDJ tool.Wash BOPE. Pull wear ring.Test BOPE. Set wear ring. Make up rotary steerable BHA. RIH to 1509' MD. Shallow test MWD. RIH to 5098'MD. Service rig. 00:00 01:00 1.00 8 35 PROD2 DRILL BHAH P Lay down 1 joint of 4" DP and XO, Blow down top drive and make up SLB 6-3/4"MWD tools 01:00 01:45 0.75 35 1,559 PROD2 DRILL TRIP P RIH w/FDJ tool and MWD on 5"drill pipe to 1559' MD. P/U=60K, S/O= 60K.Actual displacement=13.8 bbls, Calculated displacement= 12 bbls. 01:45 02:30 0.75 1,559 1,559 PROD2 DRILL DHEQ P M/U string to top drive w/one joint of 4"DP.Test FDJ tool, MWD signal @ 300 gpm, increased pump rate to 425 gpm,good test. L/D 4"DP and CIO elevators 02:30 02:45 0.25 1,559 1,559 PROD2 DRILL OWFF P OWFF, Static 02:45 03:30 0.75 1,559 35 PROD2 DRILL TRIP P POOH f/1559'MD to 35'MD.Actual displacement= 16.5 bbls, Calculated displacement= 12.3 bbls. 03:30 03:45 0.25 35 0 PROD2 DRILL BHAH P L/D FDJ and MWD tools. 03:45 04:45 1.00 0 0 PROD2 DRILL BHAH P Clean and clear rig floor, C/O grabbers on iron roughneck. 04:45 05:45 1.00 0 0 PROD2 WHDBO WWWH P Wash out stack for BOP test, blow down top drive and drain stack. 05:45 06:30 0.75 0 0 PROD2 WHDBO RURD P Pull wear bushing and set test plug. 06:30 07:30 1.00 0 0 PROD2 WHDBO RURD P Rig up to test BOPE. __._ _ _ __ Page 27 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 17:30 10.00 0 0 PROD2 WHDBO BOPE P PJSM,test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9& 11.Test#3: Lower IBOP, CV 5,8 and 10. Test#4:4" Dart„ CV 4,6 and 7. Test#5:4" FOSV and CV 2.Test#6: HCR choke, , &4"kill line Demco, 5" Dart. Test#7: Manual choke valve and HCR kill&5"Floor valve. Test #8:Annular preventer tested to 250/2500 psi.Test#9: Lower pipe rams. .Test#10 Top rams w/4/5" JT.Test#11 Lower rams w/4.5" JT.Test#12 Annular w/4.5"test jt. 250/2500 psi.Test#13 Top pipe rams w/5"test jt..Test#14 Lower pipe rams w/5"JT.Test#15 Annular w/5"test jt.250/2500 psi. Test#16 Blind rams, CV 3. Accumulator test: system pressure=2900 psi,After closing= 1700 psi,200 psi attained after 60 sec, full pressure attained after 233 sec, Five bottle nitrogen avg=2100 psi. The BOP test witness was waived, by AOGCC Rep Matt Herrera. 17:30 18:45 1.25 0 0 PROD2 WHDBO RURD P Pull test plug. Rig down test equip. Blow down lines and choke manifold. Drain stack. Set 9"ID wear ring. Clear rig floor. 18:45 19:15 0.50 0 0 PROD2 DRILL RURD P Change out elevators, prep handling tools for making up BHA. 19:15 20:45 1.50 0 373 PROD2 DRILL BHAH P Make up rotary steerable BHA as per SLB rep. 20:45 21:30 0.75 373 1,509 PROD2 DRILL TRIP P RIH f/373'MD t/1509'MD. 21:30 21:45 0.25 1,509 1,509 PROD2 DRILL DHEQ P Shallow test MWD.250 gpm, 1600 psi,47% FO 21:45 23:45 2.00 1,509 5,098 PROD2 DRILL TRIP P RIH f/1509' MD t/5098'MD. Fill pipe every 15 stds. PU 89K SO 77K Calc disp=33.23 bbls Act disp=31.87 23:45 00:00 0.25 5,098 5,098 PROD2 DRILL SVRG P Service rig, Grease swivel packing. J4/23/2015 Survey @ 5098'MD. MADD pass f/5098'MD t/5358' MD.DDrIg f/5361'MD t/5475'MD. Circ w/trouble shooting MWD data transmission problem. Pump out of hole to 5188'MD. Con't to trouble shoot MWD data transmission problem. RIH to 5475' MD. DDrIg f/5475 t/6683'MD.Circ and trouble shoot MWD depth tracking problem, DDrIg f/6683't/6706'MD. Circ and trouble shoot MWD depth tracking problem. DDrlg f/6706' MD t/6878'MD. 00:00 02:45 2.75 5,098 5,358 PROD2 DRILL SRVY P PJSM, MADD pass(cont. inclination survey) f/5098'MD to 5358'MD, 250 fph pump @ 250 gpm,2000 psi. No issues going though window and no fill observed. Page 28 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 04:30 1.75 5,358 5,475 PROD2 DRILL DDRL P Drilling ahead, L1 f/5358'MD to 5475'MD, TVD=3871'.ADT= 1.24, Bit hours= 1.24,Jar hours=2.93, P/U=90K, SIO=75K, ROT=86K. Rotate© 100 rpm's w/3K Tq on, 2K Tq off,pump @ 260 gpm w/2200 psi,41%FO, ECD= 10.78 ppg, WOB= 1-4K, Max Gas= 161 units. 04:30 06:00 1.50 5,475 5,475 PROD2 DRILL CIRC T Circulate @ 250 gpm,trouble shoot MWD data transmission to well placement engineer in Anchorage. 06:00 06:30 0.50 5,475 5,188 PROD2 DRILL TRIP T POOH @ 3 bpm f/5475 MD to 5188' MD.Actual displacement=2.5 bbls, Calculated displacement=2.6 bbls. 06:30 07:00 0.50 5,188 5,188 PROD2 DRILL CIRC T Cont.trouble shoot MWD data transmission to well placement engineer in Anchorage. 07:00 07:15 0.25 5,188 5,475 PROD2 DRILL TRIP T Decision made to drill ahead , RIH f/ 5188' MD to 5475' MD. P/U=95K, S/0=75K. After returning to bottom SLB fixed the data transmission issues and well placement is receiving data. 07:15 12:00 4.75 5,475 5,921 PROD2 DRILL DDRL P Drilling ahead, L1 f/5475'MD to 5921'MD, TVD=3875'.ADT=3.59, Bit hours=3.59,Jar hours=4.83, P/U=92K, SIO=75K, ROT=85K. Rotate @ 140 rpm's w/3K Tq on, 2K Tq off, pump @ 265 gpm w/2350 psi,41% FO, ECD= 10.84 ppg, WOB=2-4K, Max Gas=380 units. Obtain SPR's @ 5665'MD TVD= 3877' MW= 10.1 ppg ,09:00 hours MP#1,20 spm=390 psi, 30 spm= 620 psi. MP#2,20 spm=375 psi, 30 spm= 625 psi. 12:00 18:00 6.00 5,921 6,516 PROD2 DRILL DDRL P Drilling ahead, L1 f/5921'MD to 6516'MD,TVD=3902'.ADT=4.28, Bit hours=9.11,Jar hours= 10.8, P/U=99K, S/O=65K, ROT=82K. Rotate @ 140 rpm's w/4K Tq on,3K Tq off, pump @ 267 gpm w/2350 psi,41%FO, ECD= 11.04 ppg, WOB=2-5K, Max Gas=415 units. Page 29 of 70 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:15 1.25 6,516 6,683 PROD2 DRILL DDRL P Drilling ahead, L1 f/6516'MD to 6683' MD, TVD=3908'.ADT= 1.06, Bit hours= 10.17,Jar hours= 11.86, P/U= 100K, S/O=68K, ROT=82K. Rotate @ 140 rpm's w/4K Tq on, 3K Tq off, pump @ 265 gpm w/2325 psi,41%FO, ECD= 11.03 ppg, WOB=2-5K, Max Gas=315 units. 19:15 20:00 0.75 6,683 6,683 PROD2 DRILL CIRC T Circ and trouble shoot MWD depth tracking problem. 20:00 20:30 0.50 6,683 6,706 PROD2 DRILL DDRL P Drilling ahead, L1 f/6683'MD to 6706' MD,TVD=3911'.ADT=.15, Bit hours= 10.32,Jar hours= 12.01, P/U= 100K,SIO=68K, ROT=82K. Rotate @ 140 rpm's w/4K Tq on, 3K Tq off,pump @ 265 gpm w/2350 psi,41% FO, ECD=11.04 ppg, WOB=2-4K, Max Gas=415 units. .Obtain SPR's @ 6696'MD TVD= 3910' MW= 10.1 ppg, 20:30 hours MP#1,20 spm=370 psi, 30 spm= 600 psi. MP#2,20 spm=360 psi, 30 spm= 640 psi. 20:30 21:30 1.00 6,706 6,706 PROD2 DRILL CIRC T Circ and trouble shoot MWD depth tracking problem. 21:30 00:00 2.50 6,706 6,878 PROD2 DRILL DDRL P Drilling ahead, L1 f/6706'MD to 6878' MD,TVD=3920'.ADT=1.82, Bit hours= 12.14,Jar hours= 13.83, P/U= 102K, S/O=68K, ROT=83K. Rotate @ 140 rpm's w/4K Tq on, 3K Tq off, pump @ 257 gpm w/2300 psi,41% FO, ECD= 11.10 ppg, WOB=2-4K, Max Gas=415 units. 34/24/2015 Directional drill L1 lateral as per plan f/6878' MD t/8678'MD. 3912'TVD 00:00 06:00 6.00 6,878 7,462 PROD2 DRILL DDRL P Drilling ahead, L1 f/6878 MD to 7462'MD,TVD=3908'.ADT=4.52, Bit hours= 16.66,Jar hours= 18.35, P/U= 102K,S/0=70K, ROT=85K. Rotate @ 140 rpm's w/4K Tq on, 3K Tq off, pump @ 260 gpm w/2450 psi,41% FO, ECD= 11.15 ppg, WOB=2-5K, Max Gas=340 units. Page 30 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 7,462 7,875 PROD2 DRILL DDRL P Drilling ahead, L1 f/7462 MD to 7875 MD,TVD=3907'.ADT=3.34, Bit hours=20.0, Jar hours=21.69, P/U= 100K,S/O=68K, ROT=86K. Rotate @ 140 rpm's w/4K Tq on,3K Tq off, pump @ 260 gpm w/2500 psi,41%FO, ECD= 11.27 ppg, WOB=1-3K, Max Gas=426 units. Obtain SPR's @ 7785'MD,3906 TVD MW= 10.1+ppg, 09:30 Hours MP#1,20 spm=420 psi,30 spm= 640 psi MP#2, 20 spm=440 psi,30 spm= 660 psi 12:00 18:00 6.00 7,875 8,313 PROD2 DRILL DDRL P Drilling ahead, L1 f/7875'MD t/8313' MD,TVD=3910'.ADT=3.67, Bit hours=23.67, Jar hours=25.36, P/U= 102K, S/0=65K, ROT=82K. Rotate @ 140 rpm's w/4-5K Tq on, 3K Tq off, pump @ 266 gpm w/2525 psi,41%FO, ECD= 11.23 ppg, WOB=3-5K, Max Gas=356 units. 18:00 00:00 6.00 8,313 8,678 PROD2 DRILL DDRL P Drilling ahead, L1 f/8313'MD t/8678' MD, TVD=3912'.ADT=3.69, Bit hours=27.36,Jar hours=29.05, P/U= 100K, S/O=67K, ROT=82K. Rotate @ 140 rpm's w/5K Tq on,3K Tq off, pump @ 260 gpm w/2600 psi,41%FO, ECD= 11.26 ppg, WOB=2-11K, Max Gas=426 units. Obtain SPR's @ 8405'MD, 3912 TVD MW= 10.1+ppg, 19:00 Hours MP#1,20 spm=430 psi, 30 spm= 710 psi MP#2,20 spm=450 psi, 30 spm= 700 psi 04/25/2015 TD L1 lateral @ 9003' MD. CBU. OWFF. BROOH to 5572'MD. Pump out of hole to 5162'MD. CBU. OWFF TIH and place circ sub @ 5175'MD.Attempt to open circ sub. Unsuccessful. OWFF. Pump out of hole to 4909' MD. POOH to 2640'MD.Attempt to open circ sub. Unsuccessful. POOH to 373'MD.OWFF. Lay down BHA 00:00 04:00 4.00 8,678 9,003 PROD2 DRILL DDRL P Drilling ahead, L1 ff 8678'MD t/9003' MD,TVD=3914'.ADT=2.82, Bit hours=30.18,Jar hours=31.87, P/U= 100K, S/0=67K, ROT=85K. Rotate @ 140 rpm's w/5K Tq on, 4.5K Tq off, pump @ 263 gpm w/ 2680 psi,40%FO, ECD= 11.46 ppg, WOB=3-5K, Max Gas=367 units. �_� Page 31 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 9,003 9,003 PROD2 CASING CIRC P Take survey, downlink zero deflection command to PowerDrive RSS, obtain SPR's Obtain SPR's @ 9003'MD, 3914' TVD MW= 10.2 ppg, 04:10 Hours MP#1,20 spm=470 psi, 30 spm= 780 psi MP#2,20 spm=490 psi,30 spm= 800 psi 04:15 05:00 0.75 9,003 9,003 PROD2 CASING CIRC P Circ 1/2 BU. 263 gpm,2680 psi. 140 rpm. 05:00 05:30 0.50 9,003 9,003 PROD2 CASING OWFF P OWFF. Fluid level dropped 8"in 30 mins. 05:30 13:00 7.50 9,003 5,162 PROD2 CASING BKRM P BROOH f/9003' MD t/5572'MD.260 gpm,2625 psi,40%FO, 800-1000 fph.Calc disp=21.6 bbls Act disp=30.61 bbls 13:00 14:00 1.00 5,162 5,162 PROD2 CASING CIRC P CBU. 265 gpm, 2000 psi, 100 rpm, 3K tq, 39% FO, Reciprocate f/5162' MD t/5098'MD 14:00 14:15 0.25 5,162 5,162 PROD2 CASING OWFF P OWFF. Static 14:15 14:30 0.25 5,162 5,351 PROD2 CASING TRIP P TIH to 5351'MD. Position circ sub @ 5175' MD. 14:30 16:15 1.75 5,351 5,351 PROD2 CASING CIRC P Establish circ parameters. 2 bpm, 360 psi, Drop 1.75"opening ball. Pump 2 DP volumes @ 2 bpm. No indication of circ sub opening. Increase rate to 4 bpm, 950 psi and pump 1 DP volume. . No indication of circ sub opening. Consult with Well Commander Rep.Shut down pump and wait 5 mins.Attempt to seat ball ©3 bpm. No indication of circ sub opening. Rotate and reciprocate 20 rpm,3K tq.No indication of circ sub opening. Consult w/town engineer. Decision made to POOH. 16:15 16:30 0.25 5,351 5,351 PROD2 CASING OWFF T OWFF. Static. 16:30 17:30 1.00 5,351 4,909 PROD2 CASING PMPO T Pump out of hole f/5351'MD t/4909' MD.3 b[m,600 psi, Calc disp=2.7 bbls Act disp=3.82 bbls 17:30 20:00 2.50 4,909 2,640 PROD2 CASING TRIP T POOH f/4909't/2640'MD. Calc disp=12.96 bbls Act disp=15.81 bbls 20:00 20:45 0.75 2,640 2,640 PROD2 CASING CIRC T Circ pipe volume and attempt to open circ sub. 2 bpm, 250 psi, 18%FO. No indication of circ sub opening. Blow down TD. 20:45 22:00 1.25 2,640 373 PROD2 CASING TRIP T POOH f/2640' MD t/373'MD. Calc disp=12.4 bbls Act disp=14.79 bbls 22:00 22:30 0.50 373 373 PROD2 CASING OWFF T OWFF. Static Page 32 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 373 47 PROD2 CASING BHAH T Stand back HWDP and jars. Lay down BHA. Found closing ball sitting on top of a loose float in the circ. sub. 04/26/2015 Con't to lay down BHA.Clean and clear floor.MU clean out BHA. RIH to 5208' MD. Circ 1/2 BU.POOH to 5180' MD. CBU 3 1/2 x©570 gpm.. OWFF. RIH to 9003'MD. CBU. Displace to 10.3 ppg SFOBM. OWFF. Pump out of hole f/9003'MD t/5132'MD. OWFF. Pump out of hole f/5132'MD t/3966' MD. POOH on elevators f/3966'MD t13020'MD. Improper hole fill. Pump out of hole f/3020' MD t/2452'MD. 00:00 00:30 0.50 47 0 PROD2 CASING BHAH T PJSM, Cont to L/D BHA as per SLB. 00:30 00:45 0.25 0 0 PROD2 CASING BHAH T Clean and clear rig floor. SIMOPS, mobilize BHA to rig floor for clean out run. 00:45 01:45 1.00 0 281 PROD2 CASING BHAH T PJSM, M/U Clean out BHA, PDC bit RR w/jets out, NMFC, HWDP and Jars as per SLB. 01:45 03:45 2.00 281 5,208 PROD2 CASING TRIP T RIH f/281'MD to 5208,bottom of the window.Actual displacement=29.33 bbls, Calculated displacement= 31.71 bbls. 03:45 05:45 2.00 5,208 5,180 PROD2 CASING CIRC T Circulate 1/2 bottom up from bottom of window to top©5191, pump @ 265 gpm,42%FO. Pull up above top of window and cont circulating hole clean©570 gpm=3525 psi, 100 rpm's w/2 K Tq. Pumped a total of 4 BU,observed shakers with very heavy cuttings load at bottoms up. 05:45 06:00 0.25 5,180 5,180 PROD2 CASING CIRC P Obtain SPR's and blow down top drive. 06:00 06:15 0.25 5,180 5,180 PROD2 CASING OWFF P OWFF. Static 06:15 08:15 2.00 5,180 8,979 PROD2 CASING TRIP P RIH f/5180'MD t/8979'MD. Calc disp=21.6 bbls Act disp=21.12 bbls 08:15 08:30 0.25 8,979 9,003 PROD2 CASING REAM P PU single jt DP.Wash and ream f/8979'MD t/9003'MD. 265 gpm, 1480 psi, 30 rpm,4K tq, PU 98K, SO 68K, ROT 84K. 08:30 09:45 1.25 9,003 9,003 PROD2 CASING CIRC P CBU. 265 gpm, 1480 psi,41% FO, 120 rpm,4K tq, Max gas at BU=248 units 09:45 12:30 2.75 9,003 9,003 PROD2 CASING DISP P Displace well from 10.1 ppg MOBM to 10.3 ppg SFOBM as per schedule. Obtain SPR's©8972'MD, 3914' TVD MW= 10.2 ppg, 12:24 Hours MP#1,20 spm=960 psi, 30 spm= 1220 psi MP#2,20 spm=970 psi, 30 spm= 1230 psi 12:30 13:00 0.50 9,003 9,003 PROD2 CASING OWFF P OWFF.Static 13:00 19:30 6.50 9,003 5,132 PROD2 CASING PMPO P Lay down single jt DP. Pump out of hole f/8979' MD t/5132'MD. 3 bpm, 1175 psi,24%FO, PU 92K SO 64K ROT 85K Page 33 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 5,132 5,132 PROD2 CASING OWFF P OWFF. Static. 20:00 21:30 1.50 5,132 3,966 PROD2 CASING PMPO P Pump out of hole f/5132'MD t/3966' MD. 3 bpm, 700 psi,25%FO, PU 84K SO 78K 21:30 21:45 0.25 3,966 3,966 PROD2 CASING RURD P Blow down TD. Line up on trip tank. 21:45 23:15 1.50 3,966 3,020 PROD2 CASING TRIP P POOH on elevators f/3966'MD t/3020' MD. Hole not taking proper displacement. Calc disp=5.4 bbls Act disp=4.59 bbls 23:15 00:00 0.75 3,020 2,452 PROD2 CASING PMPO P Pump out of hole f/3020'MD t/2452' MD. 3 b9m,400 psi, 27%FO, Cal disp=2.7 bbls Act disp=3.85 bbls. OA=10 psi 04/27/2015 Pump out of hole to 2076'MD. POOH on elevators to 281'MD. OWFF. Lay down cleanout BHA. Change over handling equip.to 5".Service rig. Make up whipstock retrieval BHA.TIH to 1510'MD.Shallow test MWD. TIH to 5197'MD. Pull whipstock. Monitor well. Drop ball and open pump out sub. Pump out of hole to 2000' MD.TOH and lay down whipstock retrieval BHA. Inspect and lay down whipstock. Clean and clear rig floor. 00:00 00:45 0.75 2,452 2,076 PROD2 CASING PMPO P PJSM, Cont to POOH w/pump©3 bpm=350 psi,f/2452'MD to 2076' MD.Actual displacement=9.1 bbls, Calculated displacement=5.96 bbls. 00:45 01:45 1.00 2,076 281 PROD2 CASING TRIP P POOH on elevators f/2076'MD to 281'MD.Actual displacement= 14.28 bbls, Calculated displacement= 13.34 bbls. 01:45 02:00 0.25 281 281 PROD2 CASING OWFF P OWFF, slight flow to static. 02:00 02:30 0.50 281 0 PROD2 CASING BHAH P Stand back 2 stands of HWDP, LID BHA as per SLB rep. 02:30 03:15 0.75 0 0 PROD2 CASING BHAH P Clean and clear rig floor. 03:15 06:15 3.00 0 0 COMPZ CASING RURD P C/O saver sub from 4"XT-39 to 5" DP, 4-1/2"IF. 06:15 06:45 0.50 0 0 COMPZ CASING SVRG P Service rig. 06:45 07:30 0.75 0 0 COMPZ CASING BHAH P PJSM, Mobilize Baker tools for BHA #14 to rig floor. 07:30 08:30 1.00 0 108 COMPZ CASING BHAH P M/U BHA#14 as per Baker fishing rep and MWD personal. 08:30 09:00 0.50 108 1,510 COMPZ CASING TRIP P RIH w/5"DP f/108' MD to 1510'MD 09:00 09:30 0.50 1,510 1,510 COMPZ CASING DHEQ P Shallow hole test MWD tools as per SLB. 09:30 11:00 1.50 1,510 5,144 COMPZ CASING TRIP P RIH f/1510'MD to 5144'MD.Actual displacement=45.26 bbls, Calculated displacement=45.46 bbls. 11:00 11:15 0.25 5,144 5,144 COMPZ CASING CIRC P Obtain parameters. PU 112K, SO 95K. Orient tool face 10°R of high side. 11:15 11:45 0.50 5,144 5,137 COMPZ CASING OTHR P Hook whipstock @5197'MD. PU to 135K.Allow jar to bleed open. PU to 165K. Observe weight drop to 115K. POOH to 5137'MD w/5K overpull 11:45 12:15 0.50 5,137 5,137 COMPZ CASING OWFF P OWFF. Page 34 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 12:45 0.50 5,137 5,137 COMPZ CASING CIRC P Drop ball for pump out sub. Pump @ 4 bpm, 700 psi ball on seat. Pressure up to 1800 psi and shear open pump out sub. Obtain SPR's 12:45 13:15 0.50 5,137 5,137 COMPZ CASING CIRC P CBU, 360 gpm, 900 psi, 52%FO, Reduce rate to 275 gpm @ 2100 stks, 700 psi,46%FO. 13:15 14:30 1.25 5,137 5,137 COMPZ CASING OWFF P Slight flow to static 14:30 19:30 5.00 5,137 1,979 COMPZ CASING PMPO P Pump out of hole f/5137'MD t/1979' MD as per trip schedule.350 gpm, 850 psi, 54%FO Calc disp=18.35 bbls Act disp=30.45 bbls. 19:30 21:00 1.50 1,979 165 COMPZ CASING TRIP P POOH on elevators f/1979'MD t/109' MD. 21:00 22:30 1.50 165 109 COMPZ CASING BHAH P Lay down whipstock retrieving BHA as per Baker and SLB reps. Calc disp=14.14 bbls Act disp=20.4 bbls. 22:30 23:45 1.25 109 0 COMPZ CASING BHAH P Make up whipstock lifter, POOH and confirm whipstock to anchor offset @ 10°L. 23:45 00:00 0.25 0 0 COMPZ CASING BHAH P Clean and clear rig floor 04/28/2015 Lay down Baker BHA. Make up SBD assy and TIH to 1521'MD. Shallow test MWD. TIH to 5267'MD. Orient SBD and latch into MLZXP. Release FJD tool.TOH. Lay down BHA 15. Rig up to run liner. Run slotted/blank liner as per detail to 3740'MD. P/U RAM hanger assembly. 00:00 02:00 2.00 0 0 COMPZ CASING BHAH P PJSM, Clean Baker boot baskets and clear Baker tools from rig floor. 02:00 02:45 0.75 0 0 COMPZ CASING RURD P PJSM, Mobilize casing tools to rig floor and rig up to run SBD. Fire Drill CRT 78 sec @ 02:00 hrs. 02:45 03:45 1.00 0 117 COMPZ CASING PUTB P PJSM, Make up Baker Seal Bore Diverter, DB Nipple and RAM ML Production Anchor as per Baker rep. 03:45 04:15 0.50 117 117 COMPZ CASING DHEQ P Test Baker FDJ running tool as per Baker. 04:15 04:45 0.50 117 117 COMPZ CASING BHAH P M/U SLB MWD tools as per SLB rep. 04:45 05:45 1.00 117 1,521 COMPZ CASING RCST P RIH w/Baker Seal Bore Diverter on 5"DP f/117'MD to 1521'MD. 05:45 06:00 0.25 1,521 1,521 COMPZ CASING DHEQ P Shallow hole test MWD tools as per SLB. 06:00 08:30 2.50 1,521 5,246 COMPZ CASING RCST P Cont to RIH w/Baker Seal Bore Diverter on 5" DP f/1521'MD to 5246'MD. Actual displacement= 45.85 bbls, Calculated displacement=44.4 bbls Page 35 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 5,246 5,175 COMPZ CASING OTHR P Latch RAM ML Anchor into MLZXP as follows. P/U working single and establish parameters. P/U=105K, S/O=93K, Pump @ 300 gpm=1100 psi to sync MWD,49%flow out. Slack off to 5246'MD, orient tool face to 40°L,slack off to 5267'MD, observed tool face shift to 15°L when latched and observed seals entering SBE 5'before latch. P/U to 145K (40K over)to confirm latch up. Slack off to 85K, increase pump rate to 500 gpm=2150 psi to release from SBD. P/U to 5155'MD(10'), no overpull observed.Top of SBD©5184.63' MD 09:00 09:30 0.50 5,175 5,175 COMPZ CASING OWFF P Monitor well,static. 09:30 13:45 4.25 5,175 1,990 COMPZ CASING PMPO P PJSM,pump out of hole f/ 5175-1990' MD, 3 bpm,450-300 psi, FO 25%, calculated fill 27.3, actual 33.6 bbls. 13:45 15:30 1.75 1,990 46 COMPZ CASING TRIP P PJSM, blow down TD, TOH f/ 1990'-46'MD, calculated fill 15.37, actual 18.53 bbls. 15:30 16:00 0.50 46 0 COMPZ CASING BHAH P PJSM, lay down BHA per Baker& SLB reps. 16:00 17:00 1.00 0 0 COMPZ CASING BHAH P Clear&clean rig floor. 17:00 18:15 1.25 0 0 COMPZ CASING RURD P Rig up to run 4.5"liner,mobilize Hydroforms to rig floor. 18:15 22:45 4.50 0 3,740 COMPZ CASING PUTB P PJSM, P/U 4.5", 11.6#, L-80, IBTM, liner as per detail f/0-3740' MD, PU 66K, SO 63K, calculated displacement 16.71, actual 16.49 bbls. 22:45 00:00 1.25 3,740 3,780 COMPZ CASING OTHR P PJSM, P/U RAM hanger assembly as per Baker Rep.f/3740'-3780'MD. 34/29/2015 Run liner in the hole on DP to 8960'MD. Set RAM hanger as per Baker. TOH laying down running tools. Rig up&run LEM/MLZXP hanger packer. Orient&latch in LEM. Set MLZXP hanger packer top @ 4918'MD. 00:00 04:00 4.00 3,780 8,871 COMPZ CASING RUNL P PJSM, run 4.5", 11.6#, L-80, IBTM, liner on 5"DP f/3780'-8871'MD, PU 120K, SO 87K, calculated displacement 42.9, actual 42.7 bbls. 04:00 04:15 0.25 8,871 8,959 COMPZ CASING WASH P Wash down f/8821'-8959'MD,5 bpm, 950 psi, PU 122K, SO 87K. _ 'aae 36 of 70 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 06:00 1.75 8,959 5,208 COMPZ CASING HOSO P PJSM, snap in RAM hanger @ 8960.7'MD. Slack of to 47K, PU 175K&observe RAM hanger snap out. Drop 29/32"ball,snap in to 47K. Pump down ball at 4 bpm, 775 psi, FO 32%. Observe ball on seat @ 2 bpm, 500 psi, FO 21%. Stage up pressure up to 4100 psi&bleed off. Pick up to 150K observe hanger didn't release. Repeat steps holding 4100 for 5 min with no release. Repeat steps&pressure up to 4600 psi,observing ball seat shear. Pick up f/5268'-5188'MD, PU 114K. Slack off to tag seal bore diverter with nose guide @ 5208'MD. 06:00 06:30 0.50 5,208 5,208 COMPZ WELLPF OWFF P Monitor well, fluid level dropped 3". 06:30 07:15 0.75 5,208 4,762 COMPZ WELLPF PMPO P PJSM, pump out of hole f/ 5208'-4762'MD, 3 bpm,440 psi, calculated fill 3.9,actual 5.25 bbls. 07:15 10:30 3.25 4,762 100 COMPZ WELLPF TRIP P PJSM,TOH f/4762'-100',calculated fill 39.3, actual 42 bbls. Kick w/Tripping Drill CRT 46 sec @ 10:30 hrs. 10:30 11:00 0.50 100 100 COMPZ WELLPF OWFF P Monitor well, static. 11:00 11:30 0.50 100 0 COMPZ WELLPF BHAH P PJSM, lay down pups&running tools as per Baker. 11:30 12:00 0.50 0 0 COMPZ WELLPF BHAH P PJSM, blow down TD, clear&clean rig floor. OA pressure 130 psi. 12:00 13:15 1.25 0 0 COMPZ RPCOM BHAH P PJSM, rig up to make up LEM BHA. 13:15 14:30 1.25 0 0 COMPZ RPCOM BHAH P PJSM, make up slim hole MWD per SLB&lay down in pipe shed. 14:30 15:30 1.00 0 250 COMPZ RPCOM PUTB P PJSM, M/U LEM assembly as per Baker Rep. 15:30 15:45 0.25 250 250 COMPZ RPCOM BHAH P PJSM, rig up false table&change out handling tools. 15:45 17:00 1.25 250 289 COMPZ RPCOM BHAH P PJSM, pick up MLZXP liner hanger packer, slim hole MWD,orient MWD w/LEM&MLZXP. 17:00 18:00 1.00 289 1,424 COMPZ RPCOM RCST P PJSM,TIH f/289'-1424'MD. 18:00 19:30 1.50 1,424 1,424 COMPZ RPCOM DHEQ P Shallow hole test MWD @ 70 gpm, 475 psi, FO 13%. Bleed pulsation damper on mud pumps to 400 psi to get a signal. Man Down Drill CRT 75 sec©21:30 hrs. 19:30 22:15 2.75 1,424 5,147 COMPZ RPCOM RCST P PJSM,continue TIH f/1424'-5147' MD, PU 104K, SO 92K, calculated displacement 43.04, actual 43.65 bbls. 22:15 22:45 0.50 5,147 5,147 COMPZ RPCOM CIRC P Break circulation to establish parameters©70-80 gpm,650-725 psi, FO 14-15%, orient tool face to 0° high side. Page 37 of 70 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 5,147 4,918 COMPZ RPCOM PACK P TIH f/5147'-5207'MD,snap in to RAM hanger w/SO 77K. Unsnap with PU 127K. Snap back in&drop 1.5"ball. Pump ball down @ 2 bpm, 800 psi, FO 15%, ball on seat w/680 strokes, pressuring up to 1500 psi. Hold for 2 min&increase pressure in 500 psi increments to 2500 psi. Observe packer shear at 2600 psi hold for 5 min. Pressure up to 3600 observe neutralizer shear. Pressure up&hold 4000 psi for 5 min.w/SO 55K. Bleed of pressure&pick up to observe release. MLZXP liner hanger packer top set at 4918'MD. 04/30/2015 Test MLZXP hanger packer to 3000 psi.TOH&lay down running tools with slim hole MWD. Slip&cut drill line. Pick up Whipstock&milling assembly. TIH &set Whipstock.Test MLZXP seals. Displace SFOBM to 10.1ppg Faze-Pro MOBM. Mill L2 window f/4874'-4878' MD. 00:00 00:15 0.25 4,918 4,981 COMPZ RPCOM RURD P Rig up to test MLZXP. 00:15 00:30 0.25 4,981 4,981 COMPZ RPCOM PRTS P Test MLZXP to 3000 psi down IA, good test. 00:30 00:45 0.25 4,981 4,930 COMPZ RPCOM TRIP P Pick up,confirm release of running tool, pick up f/4981'MD to 4930' MD. 00:45 01:15 0.50 4,930 4,939 COMPZ RPCOM OWFF P OWFF,static. 01:15 03:30 2.25 4,939 3,086 COMPZ RPCOM PMPO P POOH,w/pump @ 3 bpm=400 psi, 24%flow f/4939'MD to 3086'MD. Actual displacement=17.85 bbls, Calculated displacement=15.6 bbls. 03:30 05:30 2.00 3,086 100 COMPZ RPCOM TRIP P POOH on elevators as per trip schedule f/3086'MD to 100' MD. Actual displacement=27.2 bbls, Calculated displacement=25.26 bbls. 05:30 05:45 0.25 100 100 COMPZ RPCOM OWFF P OWFF,static. 05:45 06:45 1.00 100 0 COMPZ RPCOM BHAH P PJSM, L/D Baker running tools and MWD. 06:45 08:15 1.50 0 0 COMPZ RPCOM BHAH P PJSM, clear&clean rig floor. 08:15 09:30 1.25 0 0 COMPZ RPCOM SLPC P PJSM,slip&cut 71'of drilling line. 09:30 10:00 0.50 0 0 COMPZ RPCOM SVRG P PJSM,service rig. 10:00 11:00 1.00 0 0 PROD3 WHPST BHAH P PJSM, mobilize Baker milling BHA 17 to rig floor. 11:00 13:45 2.75 0 146 PROD3 WHPST BHAH P PJSM,make up Whipstock/milling BHA f/0'-146'MD as per Baker& SLB Reps,orient Whipstock. 13:45 15:00 1.25 146 1,550 PROD3 WHPST TRIP P PJSM,TIH f/146-1550'MD 15:00 15:15 0.25 1,550 1,550 PROD3 WHPST DHEQ P Shallow hole test MWD @ 400 gpm, 700 psi, FO 46%.Tested good. 15:15 18:00 2.75 1,550 4,844 PROD3 WHPST TRIP P PJSM, TIH f/1550'-4844'MD, PU 110K, SO 94K, 3800 fph, fill pipe every 15 stands, calculated displacement 45.24, actual 44.45 bbls. Pace 38 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 4,844 4,931 PROD3 WHPST DLOG P PJSM, pump 400 gpm, 1375 psi, FO 54%, PU 110K, SO 94K, orient Whipstock to-27.20°.TIH 4844'-4931'MD, observe latch up& tool face turn right to 2.80°.Set down 20K,then PU to 120K to confirm latch. 18:45 19:00 0.25 4,931 4,931 PROD3 WHPST PRTS P PJSM, rig up&test MLZXP seals to 700 psi for 10 min,tested good. 19:00 19:30 0.50 4,931 4,874 PROD3 WHPST DLOG P Shear milling assembly with 40K, PU 110K. Reset bit depth at 4874' MD. 19:30 21:30 2.00 4,874 4,874 PROD3 WHPST DISP P PJSM,displace SFOBM to 10.1 ppg Faze-Pro MOBM, initial 400 gpm, 1300 psi, FO 57%,slowing to 170 gpm, 380 psi, FO 33%. SPR's @ 4874'MD, 3786'ND, MW 10.1 ppg, 19:15 hrs. #1 @30= 150@40=210 #2 @ 30= 150 @ 40=220 21:30 00:00 2.50 4,874 4,878 PROD3 WHPST MILL P PJSM, mill L2 window f/4874'-4878' MD, 3786'TVD,400 gpm, 900 psi, FO 46%, PU 110K, SO 94K,WOB 2-10K, 80-90 rpm,Tq on 2-10K H2S Drill CRT 130 sec @ 23:00 hrs. 05/01/2015 Continue milling L2 window f/4878'-4891'MD, Drill f/4891'-4911' MD. Pump sweep&CBU. Perform FIT to 13.6 ppg EMW. TOH&lay down milling assembly. CIO handling equipment for 4"DP. Pick up clean out BHA 19. DDrill f/4911'-5010'MD. CBU&OWFF. 00:00 03:00 3.00 4,878 4,891 PROD3 WHPST MILL P PJSM, Mill 8-1/2"window f/4878' MD to 4891' MD. Mill @ 400 gpm=900 psi, rotate @ 80-100 rpm's, 2-10K Tq,46%flow out. TOW @ 4874'MD, BOW @ 4891'MD. 03:00 04:30 1.50 4,891 4,914 PROD3 WHPST DDRL P Drill new hole f/4891'MD to 4914' MD, upper watermellon mill 3'below bottom of window. Pump @ 405 gpm=850 psi, 53%flow out, rotate @ 100 rpms,3-4K Tq on, 3K Tq off, WOB 8-10K. P/U= 110K, S/O=91K, ROT-100K. 04:30 05:00 0.50 4,914 4,914 PROD3 WHPST REAM P Work mill through window with pumps and rotary,turn off rotary, cont to work drill string through window.Turn off pumps,cont to work drill string through window. Good window, no issues. 05:00 06:00 1.00 4,914 4,870 PROD3 WHPST CIRC P Pumps 24 bbl HiVis sweep, circulate hole clean @ 550 gpm= 1500 psi, 53%FO.Work string f/4870'MD to 4845'MD. 06:00 06:15 0.25 4,870 4,845 PROD3 WHPST TRIP P POOH,stand back one stand f/ 4870'MD to 4845'MD, blow down top drive. 06:15 06:45 0.50 4,845 4,845 PROD3 WHPST RURD P Rig up to perform FIT. 06:45 07:00 0.25 4,845 4,845 PROD3 WHPST FIT P Perform FIT to 13.6 ppg EMW,675 psi. Page 39 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:30 0.50 4,845 4,845 PROD3 WHPST RURD P R/D testing equipment and obtain SPR's. Blow down top drive and kill line. SPR's @ 4870'MD, 3774'TVD, MW 10.2 ppg, 07:30 hrs. #1 @30= 130@40=200 #2@30= 130@40=220 07:30 08:00 0.50 4,845 4,845 PROD3 WHPST OWFF P OWFF,static. 08:00 10:30 2.50 4,845 90 PROD3 WHPST TRIP P PJSM, POOH on elevators f/4845' MD to 90'MD,Actual displacement= 47.6 bbls, Calculated displacement= 42.85 bbls. 10:30 11:00 0.50 90 90 PROD3 WHPST OWFF P OWFF,static. 11:00 11:45 0.75 90 0 PROD3 WHPST BHAH P PJSM, L/D MWD tools and milling BHA, starter mill 1/16"under gauge and upper mill in gauge. Spill Drill CRT= 100 sec© 11:45 hrs. 11:45 12:30 0.75 0 0 PROD3 WHPST BHAH P PJSM,clear&clean rig floor of Baker BHA. 12:30 15:45 3.25 0 0 PROD3 WHPST RURD P PJSM, change out saver sub f/4 1/2" IF to 4"XT39, TD grabbers,&bell guide. 15:45 16:15 0.50 0 0 PROD3 WHPST RURD P PJSM,change out handling equipment f/5"to 4". 16:15 17:00 0.75 0 0 PROD3 WHPST WWWH P PJSM, rig up&flush stack, rig down stack washer. 17:00 18:30 1.50 0 0 PROD3 WHPST BHAH P PJSM, pick up BHA 19 for clean out run,f/0-354'MD. 18:30 19:00 0.50 0 1,500 PROD3 WHPST TRIP P PJSM,TIH f/354'-1500'MD, 19:00 19:15 0.25 1,500 1,500 PROD3 WHPST DHEQ P Shallow hole test MWD©220 gpm, 1400 psi,test good. 19:15 20:45 1.50 1,500 4,795 PROD3 WHPST TRIP P TIH f/1500'-4795' MD,fill every 20 stands, calculated displacement 30, actual 29 bbls. 20:45 21:00 0.25 4,795 4,914 PROD3 WHPST SRVY P Orient motor high side,220 gpm, 1670 psi. Shut down pumps&slide through window f/4795'-4914'MD. 21:00 22:15 1.25 4,914 5,010 PROD3 DRILL DDRL P PJSM, Drilling ahead, L2 f/ 4914'-5010' MD,TVD=3793', ART=.35,AST=.51,ADT=.86, Bit= .86,Jars=30.98, PU=90K,SO= 75K, ROT=85K, Tq on 2-4K, off 2K, FO 41%, ECD= ppg,WOB= 13-15K,60 rpm,220 gpm, 1825 psi, Max Gas= units. 22:15 23:45 1.50 5,010 4,890 PROD3 DRILL CIRC P CBU f/5010'-4890' MD©250 gpm, 2050 psi,60 rpm,Tq 3K, racking one stand back. SPR's©4894'MD, 3778'TVD, MW 10.2 ppg,23:25 hrs. #1 @30=360@40=581 #2@30=350@40=600 23:45 00:00 0.25 4,890 4,890 PROD3 DRILL OWFF P Monitor well,static. Page 40 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/02/2015 24 hr Summary Finish OWFF.TOH to surface, laying down BHA 19. Flush stack.Test BOPE w/4",4-1/2",&5"test jts. Test witnessed by AOGCC Rep Chuck Sheve. Pick up production L2, BHA 20.TIH&DDrill ahead per plan f/ 5010'-5148'MD. 00:00 00:15 0.25 4,890 4,890 PROD3 DRILL OWFF P PJSM, Cont to OWFF, static. 00:15 01:15 1.00 4,890 3,944 PROD3 DRILL PMPO P POOH w/pump @ 3 bpm=700 psi, 24%FO f/4890'MD to 3944'MD. Actual displacement=7.65 bbls, Calculated displacement=5.4 bbls. 01:15 03:45 2.50 3,944 354 PROD3 DRILL TRIP P POOH on elevators f/3944'MD to 354'MD.Actual displacement= 28.91 bbls, Calculated displacement=25.11 bbls. 03:45 04:00 0.25 354 354 PROD3 DRILL OWFF P OWFF,static. 04:00 05:45 1.75 354 0 PROD3 DRILL BHAH P PJSM, Stand back 2 stands HWDP and 1 stand of NMFC. L/D clean out BHA as per SLB. 05:45 07:00 1.25 0 0 PROD3 WHDBO WWWH P Pick up stack washer and wash BOP stack,cycle all BOP rams. 07:00 08:15 1.25 0 0 PROD3 WHDBO RURD P Remove wear ring, install test plug and rig up to test BOPE. 08:15 15:00 6.75 0 0 PROD3 WHDBO BOPE P PJSM,test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9&11. Test#3: Lower IBOP, CV 5,8 and 10. Test#4:4" Dart„ CV 4,6 and 7. Test#5: 4" FOSV and CV 2.Test#6: HCR choke, &4"kill line Demco,5"Dart. Test#7: Manual choke valve and HCR kill&5"Floor valve. Test#8: Annular preventer tested to 250/2500 psi.Test#9: Lower pipe rams. .Test #10 Top rams w/4/5"JT.Test#11 Lower rams w/4.5"JT.Test#12 Annular w/4.5"test jt.250/2500 psi. Test#13 Top pipe rams w/5"test jt.. Test#14 Lower pipe rams w/5"JT. Test#15 Annular w/5"test jt. 250/2500 psi.Test#16 Blind rams, CV 3. Accumulator test:fail/pss, 1st test did not pass, retest,good system pressure=3000 psi,After closing= 1600 psi,200 psi attained after 40 sec, full pressure attained after 185 sec, Five bottle nitrogen avg=2000 psi. The BOP test witnessed by AOGCC Rep Chuck Scheve 15:00 16:00 1.00 0 0 PROD3 WHDBO RURD P PJSM, rig down test equipment, blow down lines&choke manifold. 16:00 16:15 0.25 0 0 PROD3 WHDBO RURD P Insall wear bushing, 9"ID. 16:15 16:45 0.50 0 0 PROD3 DRILL RURD P Clean&clear rig floor. Page 41 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:30 1.75 0 373 PROD3 DRILL BHAH P PJSM, PU production L2 BHA 20 as per SLB Rep. f/0-373' MD. 18:30 19:00 0.50 373 1,511 PROD3 DRILL TRIP P PJSM, TIH f/373'-1511'MD. Kick w/Tripping Drill CRT=74 sec © 18:45 hrs. 19:00 19:15 0.25 1,511 1,511 PROD3 DRILL DHEQ P Shallow hole test MWD,220 gpm, 1250 psi, 25 rpm,Tq 2K, test good. 19:15 20:30 1.25 1,511 4,814 PROD3 DRILL TRIP P PJSM,TIH f/1511'-4814' MD. Calculated displacement 32, actual 31 bbls. 20:30 21:30 1.00 4,814 5,010 PROD3 DRILL SRVY P Shoot surveys f/4814'-5010' MD, (4932',4949',5001' MD)220 gpm, 2075 psi. 21:30 00:00 2.50 5,010 5,148 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/ 5010'-5148' MD, TVD=3793',ADT= 1.5, Bit= 1.5,Jars=34.23, PU= 92K, SO=77K, ROT=84K, Tq on 3-4K, off 2-3K, FO 40%, ECD=10.63 ppg,WOB=2-5K, 100 rpm,260 gpm, 2175 psi, Max Gas=301 units. SPR's©5091'MD, 3825'TVD, MW 10.1+ppg, 22:45 hrs. #1 @30=300@40=535 #2 @ 30=300 @ 40=540 OA pressure 205 psi©24:00 hrs. 05/03/2015 Directional drill L2 production section as per plan f/5148'-7085'MD. CBU at 6670'MD to alleviate increasing ECD. 00:00 06:00 6.00 5,148 5,738 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/ 5148'-5738' MD, TVD=3707',ADT= 4.82, Bit=4.82, Jars=39.05, PU= 96K, SO=657K, ROT=84K,Tq on 3-4K, off 3K, FO 40%, ECD=10.92 ppg,WOB= 10-12K, 140 rpm,260 gpm,2210 psi, Max Gas=613 units. Table Top Kick w/Tripping Drill @ 03:00 hrs. 06:00 12:00 6.00 5,738 6,323 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/5738'to 6323'MD, TVD=3827',ADT=4.45, Bit= 10.77, Jars=43.50, PU= 100K, SO=66K, ROT=85K,Tq on 3-4K, off 3K, FO 40%, ECD=11.18 ppg, WOB=7-10K, 140 rpm, 260 gpm, 2400 psi, Max Gas=721 units. SPR's @ 6232'MD, 3818'TVD, MW 10.2+ppg, 10:54 hrs. #1 @ 20=360 @ 30=600 #2@20=380@30=590 OA pressure 200 psi© 12:00 hrs. 12:00 16:15 4.25 6,323 6,670 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/6323'to 6670'MD,TVD=3833',ADT=3.32, Bit= 14.09,Jars=46.82, PU= 107K, SO=64K, ROT=83K,Tq on 3-5K, off 2-3K, FO 39%, ECD=11.40 ppg, WOB=3-6K, 140 rpm,260 gpm, 2500 psi, Max Gas=433 units. Page 42 of 70 Time Logs 11111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:15 1.00 6,670 6,670 PROD3 DRILL CIRC T CBU due to high ECD @ 270 gpm, 2650 psi, 150 rpm,Tq 3-4K, FO 41%. 17:15 18:00 0.75 6,670 6,705 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/6670'to 6705'MD, TVD=3835',ADT=.4, Bit=14.49, Jars=47.22, PU= 107K, SO=64K, ROT=83K,Tq on 3-5K, off 2-3K, FO 39%, ECD=11.40 ppg, WOB=3-6K, 140 rpm,260 gpm, 2500 psi, Max Gas=433 units. SPR's @ 6703'MD, 3833'TVD, MW 10.1+ppg, 18:00 hrs. #1 @ 20=395 @ 30=640 #2 @ 20=390 @ 30=620 18:00 00:00 6.00 6,705 7,085 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/6705'to 7085'MD,TVD=3841',ADT=4.14, Bit= 18.63, Jars=51.36, PU= 105K, SO=67K, ROT=83K,Tq on 3-4K, off 2-3K, FO 40%, ECD=11.44 ppg, WOB=2-4K, 140 rpm, 260 gpm, 2400 psi, Max Gas=538 units. SPR's @ 7085'MD, 3841'TVD, MW 10.2 ppg, 23:30 hrs. #1 @20=410@30=690 #2 @ 20=420 @ 30=690 OA pressure 205 psi @ 24:00 hrs. 05/04/2015 Directional drill L2 production section as per plan f/7085'-8996'MD. 00:00 06:00 6.00 7,085 7,537 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/7085'-7537'MD, TVD=3835',ADT= 4.75, Bit=23.38, Jars=56.11, PU= 105K, SO=67K, ROT=85K,Tq on 3-4K, off 3-5K, ECD=11.45 ppg, FO 40%,WOB=2-4K, 140 rpm,260 gpm, 2500 psi, Max Gas=630 units. 06:00 12:00 6.00 7,537 8,029 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/7537'-8029'MD, TVD=3833',ADT= 4.09, Bit=27.47, Jars=6020, PU= 105K, SO=70K, ROT=86K,Tq on 4K,off 4K, ECD=11.54 ppg, FO 40%,WOB=0-2K, 140 rpm,260 gpm, 2550 psi, Max Gas=591 units. SPR's @ 8028'MD, 3833'TVD, MW 10.1 ppg, 11:40 hrs. #1 @20=560@30=800 #2 @20=460@30=710 OA pressure 210 psi @ 12:00 hrs. 12:00 18:00 6.00 8,029 8,502 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/8029'-8502' MD, TVD=3836',ADT= 4.22, Bit=31.69,Jars=64.42, PU= 115K, SO=64K, ROT=84K,Tq on 4-5K, off 3-4K, ECD=11.71 ppg, FO 40%,WOB=3-6K, 140 rpm,260 gpm,2700 psi, Max Gas=497 units. Page 43 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 8,502 8,996 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/8502'-8996'MD, TVD=3844',ADT= 4.77, Bit=36.46, Jars=69.19, PU= 112K, SO=64K, ROT=83K,Tq on 4-5K, off 3-4K, ECD=11.76 ppg, FO 40%,WOB=2-4K, 140 rpm, 260 gpm, 2750 psi, Max Gas=560 units. SPR's @ 8784'MD, 3845'TVD, MW 10.1+ppg,21:00 hrs. #1 @ 20=480 @ 30=750 #2 @ 20=480 @ 30=760 OA pressure 170 psi @ 24:00 hrs. 35/05/2015 Directional drill L2 production section as per plan f/8996'-10743' MD. 00:00 06:00 6.00 8,996 9,482 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/8996'-9482'MD, TVD=3850', ADT= 4.31, Bit=40.77, Jars=73.50, PU= 112K, SO=65K, ROT=84K,Tq on 4-5K, off 4-5K, ECD=11.93 ppg, FO 40%,WOB=2-4K, 140 rpm,260 gpm, 2800 psi, Max Gas=561 units. 06:00 12:00 6.00 9,482 9,996 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/9482'-9996'MD, TVD=3839', ADT= 4.36, Bit=45.13, Jars=77.86, PU = 117K, SO=52K, ROT=84K, Tq on 5K, off 3K, ECD=12.14 ppg, FO 40%,WOB=3-5K, 140 rpm, 260 gpm, 2890 psi, Max Gas=561 units. SPR's @ 9921'MD, 3838'TVD, MW 10.1+ppg, 11:00 hrs. #1 @ 20=480 @ 30=750 #2 @ 20=480 @ 30=760 OA pressure 165 psi© 12:00 hrs. 12:00 18:00 6.00 9,996 10,405 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/9996'-10405'MD, TVD=3842', ADT=4.27, Bit=49.40, Jars=82.13, PU= 117K, SO=45K, ROT=81K, Tq on 6-7K, off 3-4K, ECD=12.4 ppg, FO 40%,WOB=5-6K, 140 rpm, 260 gpm, 3050 psi, Max Gas =355 units. 18:00 00:00 6.00 10,405 10,743 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/10405'-10743'MD, TVD=3851', ADT=4.04, Bit=53.44, Jars=86.17, PU= 116K, SO=58K, ROT=81K, Tq on 6K, off 4-5K, ECD=12.41 ppg, FO 40%,WOB=3-6K, 140 rpm,260 gpm, 3050 psi, Max Gas= 194 units. SPR's© 10488'MD, 3842'TVD, MW 10.15 ppg, 19:00 hrs. #1 ©20=600©30=860 #2 @ 20=600 @ 30=870 OA pressure 200 psi©24:00 hrs. Page 44 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/06/2015 24 hr Summary Directional drill L2 production section as per plan f/10743'-12183'MD. Shoot surveys at TD 12183'MD, 3862' TVD. OWFF, slight loss. BROOH f/12183'-12098'MD. 00:00 06:00 6.00 10,743 11,075 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/10743'-11075'MD, TVD=3860', ADT=4.06, Bit=57.5,Jars=90.23, PU= 115K, SO=53K, ROT=82K, Tq on 6K,off 5K, ECD=12.66 ppg, FO 40%,WOB=2-3K, 140 rpm, 260 gpm, 3150 psi, Max Gas=381 units. SPR's @ 11057'MD, 3861'TVD, MW 10.1+ppg, 05:30 hrs. #1 @20=660@30=940 #2@20=620@30=900 Spill Drill CRT 115 sec @ 04:30 hrs. 06:00 12:00 6.00 11,075 11,500 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/11075'-11500'MD,TVD=3859', ADT=4.50, Bit=62.0,Jars=94.73, PU= 111K, SO=55K, ROT=83K, Tq on 6K, off 5.5K, ECD=12.66 ppg, FO 40%,WOB=3-5K, 140 rpm,260 gpm, 3200 psi, Max Gas=445 units. OA pressure 150 psi @ 12:00 hrs. 12:00 18:00 6.00 11,500 11,909 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/11500'-11909'MD,TVD=3863', ADT=4.32, Bit=66.32, Jars=99.05, PU= 110K, SO=43K, ROT=80K, Tq on 6K, off 5K, ECD=12.67 ppg, FO 40%,WOB=3-5K, 140 rpm, 260 gpm, 3275 psi, Max Gas=467 units. 18:00 22:15 4.25 11,909 12,183 PROD3 DRILL DDRL P PJSM, DDrilling ahead, L2 f/11909'-12183'MD,ND=3862', ADT=3.11, Bit=69.43,Jars= 102.16, PU= 115K,SO=44K, ROT =80K,Tq on 6.5K, off 5K, ECD=12.67 ppg, FO 40%,WOB= 2-4K, 140 rpm, 260 gpm, 3350 psi, Max Gas=489 units. TD 12183'MD,3862'ND 22:15 23:00 0.75 12,183 12,183 PROD3 CASING CIRC P Continue circulating out high vis sweep @ 260 gpm, 3350 psi, 140 rpm,Tq 4-5K, 5-10%increase in cuttings. 23:00 23:15 0.25 12,183 12,183 PROD3 CASING SRVY P Shoot surveys at TD&obtain SPR's. SPR's @ 12183'MD, 3862'TVD, MW 10.1 ppg, 23:15 hrs. #1 ©20=640 @ 30=940 #2@20=640@30=950 23:15 23:45 0.50 12,183 12,183 PROD3 CASING OWFF P Monitor well, slight drop in fluid level. 23:45 00:00 0.25 12,183 12,098 PROD3 CASING BKRM P PJSM, BROOH f/12183'-12098' MD, 260 gpm, 3350 psi, 140 rpm, Tq 4.5K, PU 115K, SO 49K, ROT 83K. OA pressure 130 psi @ 24:00 hrs. Page 45 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/07/2015 24 hrSummary BROOH to window @ 4814'MD. CBU inside 9-5/8"casing.Activate well commander&CBU 4X.TIH to TD @ 12183'MD. CBU then displace well to 10.3 ppg SFOBM system. 00:00 12:00 12.00 12,098 4,814 PROD3 CASING BKRM P PJSM, BROOH f/12098'-4814'MD ©260 gpm, FO 40%, 3200-2300 psi, 140 rpm,Tq 4-5K, 1200 fph, PU 100K, SO 75K, ROT 84K. Calculated fill 41.58, actual 56.76 bbls. Kick w/Tripping Drill CRT 49 sec @ 04:30 hrs OA pressure 140 psi. 12:00 13:15 1.25 4,814 4,814 PROD3 CASING CIRC P CBU @ 265 gpm,2160 psi, 100 rpm, Tq 3-4K, FO 42%. 13:15 13:30 0.25 4,814 5,067 PROD3 CASING PULD P PJSM, TIH f/4814'-5067'MD, laying down a single to place the Well Commander on depth at the window. 13:30 13:45 0.25 5,067 5,067 PROD3 CASING CIRC P PJSM,drop 1-3/4"ball&pump 2 bpm, 350 psi to open Well Commander. Observe increase to 1300 psi&then decrease to open. 13:45 15:15 1.50 5,067 5,067 PROD3 CASING CIRC P CBU 4X @ 550-675 gpm, 2700-3600 psi,60 rpm,Tq 2-3K, FO 56%. Spill Drill CRT 83 sec @ 15:15 hrs. 15:15 15:45 0.50 5,067 5,067 PROD3 CASING CIRC P PJSM,drop 1-3/4"ball&pump 2 bpm, 175 psi to close Well Commander. Observe increase to 1300 psi to indicate closing. 15:45 19:45 4.00 5,067 12,183 PROD3 CASING TRIP P PJSM,TIH f/5067'-12183'MD, fill DP every 20 stands, calculated displacement 42.12, actual 39.6 bbls. 19:45 21:15 1.50 12,183 12,183 PROD3 CASING CIRC P CBU @ 270 gpm, 3400 psi, 120 rpm, Tq 6K. 21:15 00:00 2.75 12,183 12,183 PROD3 CASING DISP P PJSM, displace wet to 10.3 ppg SFOBM system. Stage pumps down to minimize ECD, 90 rpm,Tq 6-7K, 260 gpm =3350 psi;200 gpm= 3100 psi; 175 gpm=2950 psi; 150 gpm=2600 psi. OA pressure 140 psi. 35/08/2015 Finish displacement&OWFF. Pump OOH to window.TOH to surface, laying down BHA 20. Change out handling equipment for 5"DP. Slip&cut drill line. 00:00 00:45 0.75 12,183 12,183 PROD3 CASING OWFF P Monitor well,static. Obtain SPR's. Fire Drill CRT 98 sec @ 00:15 hrs. SPR's @ 12183'MD, 3862'TVD, MW 10.3 ppg, 00:30 hrs. #1 @ 20= 1540 @ 30=2060 #2©20= 1580©30=2020 00:45 11:00 10.25 12,183 4,874 PROD3 CASING PMPO P PJSM, pump OOH f/12183'-4874' MD, 3 bpm,2200 psi, FO 25%, calculated fill 40.5,actual 58.45 bbls. 11:00 12:15 1.25 4,874 4,874 PROD3 CASING CIRC P CBU @ 4-5 bpm, 1300-2400 psi,50 rpm,Tq 3-4K 12:15 12:45 0.50 4,874 4,874 PROD3 CASING OWFF P Monitor well,static. 12:45 13:45 1.00 4,874 3,890 PROD3 CASING PMPO P PJSM, pump OOH f/4874'-3890'MD, 3 bpm, 900 psi, FO 20%. 1__ __ _. . Page 46 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 17:30 3.75 3,890 450 PROD3 CASING TRIP P PJSM, TOH f/3890'-450'MD. 17:30 17:45 0.25 450 450 PROD3 0 3 CASING OWFF P Monitor well, static. 17:45 18:15 0.50 450 190 PROD3 CASING BHAH P PJSM, rack back 3 stands HWDP& jars. 18:15 19:15 1.00 190 0 PROD3 CASING BHAH P Continue laying down BHA 20 as per SLB DD. 19:15 20:15 1.00 0 0 PROD3 CASING BHAH P PJSM, clear&clean rig floor 20:15 22:15 2.00 0 0 COMPZ CASING RURD P PJSM, change out saver sub on TD &rig floor handling equipment for 5" DP. 22:15 23:00 0.75 0 0 COMPZ CASING BHAH P PJSM, mobilize whipstock retrieval tools to the rig floor. 23:00 00:00 1.00 0 0 COMPZ CASING SLPC P PJSM,slip&cut 72'of drill line. OA pressure 130 psi. 35/09/2015 Make up whipstock retrieval BHA.TIH&pull L2 whipstock. TOH&lay down assembly. Clear&clean rig floor. Change out Top Drive upper IBOP. 00:00 00:30 0.50 0 0 COMPZ CASING SLPC P PJSM,finish cut&slip 72'of drill line. 00:30 02:00 1.50 0 106 COMPZ CASING BHAH P PJSM,make up whipstock retrieval BHA 21,0-106'MD. 02:00 02:45 0.75 106 1,495 COMPZ CASING TRIP P PJSM,TIH f/106'-1495'MD. 02:45 03:00 0.25 1,495 1,495 COMPZ CASING DHEQ P Shallow test MWD @ 325 gpm, 900 psi,tested good. 03:00 04:30 1.50 1,495 4,849 COMPZ CASING TRIP P PJSM, TIH f/1495-4849'MD, calculated displacement 41, actual 59 bbls. 04:30 06:00 1.50 4,849 4,870 COMPZ CASING OTHR P PJSM, retrieve L2 whipstock. Obtain parameters PU 110K, SO 93K, 360 gpm, 1900 psi. Orient wash jet to low side w/MWD.Wash down to retrieval slot 4849-4887'MD.Work wash/jet tool across slot. Orient hook to low side. Slack off&observe hook fall into slot. PU to 120K to confirm latched at 4875'MD. PU to 150K to fire jars. PU to 160K& observe unloader shear&trip anchor. Pick up to 4870'MD, PU 115K. 06:00 06:30 0.50 4,870 4,870 COMPZ CASING OWFF P Monitor well, static. 06:30 07:00 0.50 4,870 4,852 COMPZ CASING CIRC P Drop 2.25"steel ball&pump @ 2 bpm, 100 psi,f/4870'-4852'MD. observe pump out sub shear at 1800 psi. Obtain SPR's. SPR's @ 4852'MD, 3769'TVD, MW 10.2 ppg, 07:00 hrs. #1 @ 20=390 @ 30=485 #2 @ 20=390 @ 30=460 07:00 07:30 0.50 4,852 4,852 COMPZ CASING CIRC P CBU @ 450 gpm, 1200 psi. 07:30 08:45 1.25 4,852 4,852 COMPZ CASING OWFF P Monitor well,went static after 45 min. Monitor 30 min static. 08:45 14:15 5.50 4,852 2,000 COMPZ CASING PMPO P PJSM, pump OOH f/4852'-2000'MD, 3 bpm,500-350 psi. Calculated fill 22.2, actual 33.2 bbls. Page 47 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:30 2.25 2,000 190 COMPZ CASING TRIP P PJSM, TOH f/2000'-190'MD. Calculated fill 19.4,actual 23.8 bbls. 16:30 16:45 0.25 190 190 COMPZ CASING OWFF P Monitor well, static. 16:45 17:45 1.00 190 56 COMPZ CASING BHAH P PJSM, lay down whipstock retrieval BHA 21 as per Baker Rep f/190'-56' MD. 17:45 19:15 1.50 56 56 COMPZ CASING BHAH P PJSM, clean up magnet, boot baskets, &hook. Send all down the slide. 19:15 20:15 1.00 56 0 COMPZ CASING BHAH P PJSM, lay down Whipstock, anchor, shuck, &subs.Whipstock showed a walk to the right of an inch. Orientation was verified right on. 20:15 21:15 1.00 0 0 COMPZ CASING BHAH P PJSM,clean&send down Baker tools from rig floor. 21:15 22:00 0.75 0 0 COMPZ CASING BHAH P PJSM,clean rig floor. 22:00 00:00 2.00 0 0 COMPZ CASING RGRP T PJSM, change out upper IBOP on Top Drive. OA pressure 125 psi. @ 24:00 hrs. 35/10/2015 Test Top Drive upper IBOP. Change out swivel packing on TD. Pick up SBD as per detail.TIH on 5"DP. Orient&set SBD @ left,4876' MD. Release from SDB&OWFF. Pump OOH to 1574'MD.TOH to 734' MD. 00:00 00:30 0.50 0 0 COMPZ CASING RGRP T Complete assembling new upper IBOP on top drive. 00:30 02:00 1.50 0 0 COMPZ CASING RGRP T Rig up test equipment.Test Upper IBOP to 250 psi low, 3500 high, charted, 5 mins each test. Good. Rig down test equipment 02:00 03:30 1.50 0 0 COMPZ CASING RGRP T Change out leaking swivel packing, and test to 1000 psi. 03:30 04:30 1.00 0 0 COMPZ CASING RURD P PJSM. Rig up casing running equipment. Double stacked power tongs. 04:30 08:15 3.75 0 100 COMPZ CASING BHAH P PJSM. Make up BHA for Seal Bore Diverter L2 run. Surface test FJD tool. Released with 515 gpm 750 psi. Relatch. Good test. Make up MWD tool,orient to SBD. Pick up 1 joint 5" HWDP, string magnet, bumper sub. 08:15 09:45 1.50 100 1,565 COMPZ CASING RCST P PJSM,trip in the hole with FJD,seal diverter assembly f/100'-1565'MD, on 5"DP. 09:45 10:00 0.25 1,565 1,565 COMPZ CASING DHEQ P Test MWD tool.323 gpm,670 psi. Good test. Kick w/Tripping Drill CRT 60 sec @ 10:00 hrs. 10:00 14:45 4.75 1,565 4,895 COMPZ CASING RCST P TIH to f/1565'-4895' MD.Actual fill 39.9 bbls, calculated fill 40.1 bbls. Page 48 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 16:15 1.50 4,895 4,925 COMPZ CASING OTHR P PJSM, set SBD anchor into MLZXP as per Baker Rep. Establish parameters PU 95K,SO 85K,320 gpm, 1300 psi, orient to 42°left. Wash down at 42°left f/4895'-4951' MD. Set down 15K, observing seals entering MLZXP&tool face turn to 2° left. Set down 20K then PU 75K over confirming latched up. Increase to 550 gpm, 2300 psi to release SBD. PU to 4925'MD. SPR's @ 4895'MD, 3777'TVD, MW 10.3 ppg, 15:00 hrs. #1 @20=480@30=595 #2©20=480©30=605 16:15 17:30 1.25 4,925 4,925 COMPZ CASING OWFF P Monitor well,went static after 45 min. 17:30 18:45 1.25 4,925 4,368 COMPZ CASING PMPO P PJSM,pump OOH f/4925-4368' MD, 3 bpm,600 psi, 1200 fph. 18:45 19:30 0.75 4,368 4,368 COMPZ CASING SVRG P Service rig. 19:30 23:15 3.75 4,368 1,574 COMPZ CASING PMPO P PJSM, pump OOH f/4368'-1574'MD, 3 bpm,500 psi, 1500-2000 fph. 23:15 00:00 0.75 1,574 734 COMPZ CASING TRIP P PJSM,TOH f/1574'-734'MD, calculated fill 31.2,actual 40.9 bbls. Kick w/Tripping Drill CRT 76 sec @ 23:30 hrs. OA pressure 160 psi©24:00 hrs. 05/11/2015 Finish TOH&lay down SBD running assembly BHA 22. Rig up to run L2 4-1/2"liner. Run liner as per detail. Set RAM hanger as per Baker.TOH f/4903'-3080' MD. 00:00 01:00 1.00 734 100 COMPZ CASING TRIP P PJSM,TOH f/734'-100'MD, calculated 10, actual 15.3 bbls. 01:00 02:00 1.00 100 0 COMPZ CASING BHAH P PJSM,lay down BHA 22, FJD running tool as per Baker. 02:00 03:00 1.00 0 0 COMPZ CASING BHAH P PJSM,clear&clean rig floor. 03:00 04:15 1.25 0 0 COMPZ CASING RURD P PJSM, rig up casing handling equipment. Pick up 170 6-1/8" Hydroforms&6 6-1/2"Hydroforms, staging on the rig floor. 04:15 11:45 7.50 0 7,248 COMPZ CASING PUTB P PJSM, run L2 lateral,4.5", 11.6#, L80, IBTM liner as per detail f/ 0-7248'MD. PU 70K, SO 61K before exiting window w/no problems. Ran 170 6-1/8"&6-1/2"hydroforms,with 3 stop rings on the joint above each swell packer. Calculated displacement 30.4,actual 30.2 bbls. 11:45 13:00 1.25 7,248 7,288 COMPZ CASING OTHR P PJSM, make up RAM hanger&inner string to liner,XO to drill pipe. 13:00 17:00 4.00 7,288 12,050 COMPZ CASING RUNL P PJSM,TIH f/7288'-12050'MD, Calculated displacement 40.5, actual 39.9 bbls. 17:00 17:15 0.25 12,050 12,122 COMPZ CASING WASH P Wash down f/12050'-12122'MD, 190 gpm, 950 psi, PU 125K, SO 74K, ROT 86K, 10 rpm,Tq 7K. Page 49 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:45 1.50 12,122 4,903 COMPZ CASING HOSO P PJSM, snap in RAM hanger @ 12151'MD. Slack of to 45K, PU 125K&observe RAM hanger snap out.,snap in to 40K. Pump down 29/32"ball at 4.5 bpm,975 psi, FO 16%. Observe ball on seat @ 2 bpm, 550 psi. Stage up pressure up to 4150 psi observing ball seat shear. Pick up f/4951'-4871'MD, PU 110K. Slack off to tag seal bore diverter with nose guide @ 4881'MD. Pick up to 4871'MD to CBU.Top of RAM hanger 4872' MD. 18:45 20:00 1.25 4,903 4,903 COMPZ WELLPF CIRC P CBU @ 5 bpm, 750 psi washing SBD. SPR's @ 4903'MD, 3781'TVD, MW 10.3 ppg, 19:45 hrs. #1 @20=390@30=500 #2 @ 20=390 @ 30=480 20:00 21:00 1.00 4,903 4,903 COMPZ WELLPF OWFF P Monitor well,went static after 30 min, then observe static 30 min. 21:00 00:00 3.00 4,903 3,080 COMPZ WELLPF PMPO P PJSM, pump OOH f/4903'-3080'MD, 3 bpm,450 psi, 1500 fph. Calculated fill 11.7,actual 15 bbls. OA pressure 185 psi @ 24:00 hrs. 35/12/2015 Continue pumping OOH to 1964'MD. OWFF.TOH to surface, laying down Baker running tool.Rig up to pick up LEM&MLZXP assy's. Pick up LEM&MLZXP assemblies,TIH on 5"DP to 1451'MD. Shallow test MWD.TIH to 4803'MD Orient&set as per Baker Rep. Pressure test the MLZXP&9-5/8"casing. Pump OOH to 1310'MD as per schedule. 00:00 01:45 1.75 3,080 1,964 COMPZ WELLPF PMPO P Continue to pump out of the hole from 3080'to 1964' MD. 3 bpm,300 psi.Actual displacement=12.6 bbls, calc=11.7 bbls 01:45 02:00 0.25 1,964 1,964 COMPZ WELLPF OWFF P Observe well for flow. Static. 02:00 05:00 3.00 1,964 0 COMPZ WELLPF TRIP P POOH on elevators from 1964'. 05:00 06:00 1.00 0 0 COMPZ WELLPF BHAH P Lay down running tools. Clean and clear rig floor. 06:00 06:30 0.50 0 0 COMPZ RPCOM BHAH P RU csg.equip. PU Baker handling tools. 06:30 11:00 4.50 0 513 COMPZ RPCOM PUTB P MU LEM/hanger packer assy as per Baker rep. LEM assy,4.5" 11.6#IBTM pup jt, 10 jts 4.5#IBTM blank pipe, SBE. RU false table and MU slim hole MWD. Orient LEM. MU MLZXP liner hanger packer. 11:00 12:00 1.00 513 1,451 COMPZ RPCOM RCST P RIH w/LEM/hange packer assy on DP f/513' MD t/1451 MD. Calc disp=l2 bbls Act Disp=15.5 bbls 12:00 12:15 0.25 1,451 1,451 COMPZ RPCOM DHEQ P Shallow hole test MWD.2 bpm,575 psi. 12:15 15:15 3.00 1,451 4,803 COMPZ RPCOM RCST P RIH w/LEM/hange packer assy on DP f/1450'MD t/4803'MD. Calc disp=31.2 bbls Act Disp=30.1 bbls _ lag e 50 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:45 1.50 4,803 4,890 COMPZ RPCOM PACK P Brk circ. Establish parameters. PU 101K, SO 90K, Orient to 30°left. RIH slowly to 4890'MD and latch LEM into RAM hanger. Set down 20K wt. (MWD rotated t/6°right). PU and attempt to snap out of collet w/20K over pull. Unable to snap out. Drop 1.5"setting ball. 16:45 17:15 0.50 4,890 4,890 COMPZ RPCOM PACK P Pump ball down @ 2 bpm, 950 psi. With ball on seat pressure up to 2500 psi. Hold 5 mins. Pressure up to 3500 psi to set MLZXP and hanger. Pressure up to 4000 psi to fully release from stetting tool. Bleed off pressure and pick up to observe release. MLZXP liner hanger packer top set at 4390'MD 17:15 17:45 0.50 4,890 4,890 COMPZ RPCOM PRTS P Test packer to 3000 psi/10 min on chart 17:45 18:45 1.00 4,890 4,291 COMPZ RPCOM CIRC P Rack back one stand of DP. CBU. 350 gpm, 1000 psi 18:45 19:45 1.00 4,291 4,291 COMPZ RPCOM OWFF P OWFF. Slight flow tapering off to static. 19:45 20:00 0.25 4,291 4,291 COMPZ RPCOM CIRC P Obtain SPR's @ 4291'MD.3716' TVD. 10.3 ppg MW. 19:45 hrs. #1 20spm=340 psi 30spm =450 psi #2 20spm=350 psi 30spm =450 psi 20:00 00:00 4.00 4,291 1,310 COMPZ RPCOM PMPO P Pump out of hole f/4291'MD t/1310' MD as per trip schedule. OA=150 psi. 35/13/2015 TOH. Lay down running tools. Make up whipstock and milling assy's.TIH to 4403'MD.Set whipstock. Shear milling assy. Displace 10.3 ppg SFOBM w/10.2 ppg Faze-Pro MOBM. Mill window in casing to 4360' MD. 00:00 02:30 2.50 1,310 0 COMPZ RPCOM TRIP P PJSM.Trip out of the hole on elevators from 1320'to surface. Lay down MLZXP running tools, and SLB super slim MWD tool string.Actual fill=15.34 bbls. Calc.fill=13.2 bbls. 02:30 04:15 1.75 0 0 PROD4 WHPST BHAH P Clear and clean rig floor, Pick up Baker mills,tools, subs to the rig floor via beaver slide. 04:15 06:15 2.00 0 0 PROD4 WHPST BHAH P Pick up from pipe shed. 3 spiral 6'/z" drill collars, and 9 5"HWDP. Stand back in derrick. 06:15 09:45 3.50 0 137 PROD4 WHPST BHAH P PJSM. Pick up and make up whipstock assembly as per Baker rep.to 137'. 09:45 11:45 2.00 137 1,538 PROD4 WHPST TRIP P Trip in the hole with whipstock for L3. Shallow pulse test. @ 970'MD. 310 gpm, 73 spm,490 psi.TIH to 1538' MD. 11:45 12:15 0.50 1,538 1,538 PROD4 WHPST DHEQ P Shallow pulse test MWD. 12:15 14:45 2.50 1,538 4,372 PROD4 WHPST TRIP P RIH f/1538'MD t/4372'MD. Page 51 of 70 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 4,372 4,372 PROD4 WHPST CIRC P Establish parameters. PU 112K, SO 85K, 300 gpm, 1450 psi. Orient MWD to 43°left of high side. 15:00 16:00 1.00 4,372 4,403 PROD4 WHPST DLOG P RIH and land anchor on depth @ 4403'MD. Set down 10k wt. PU 10K overpull and verify anchor is latched. Final whipstock orientation is 30°left of high side. Shear out milling assy. w/35K down wt. TOW @ 4346'MD. 16:00 16:15 0.25 4,403 4,335 PROD4 WHPST SFTY P PJSM on displacing well. 16:15 18:15 2.00 4,335 4,335 PROD4 WHPST DISP P Displace well f/10.3 ppg SFOBM t/ 10.2 FazePro MOBM. 5 bpm@ 500 psi. 18:15 19:30 1.25 4,335 4,335 PROD4 WHPST PRTS P Rig up and test MLZXP seal assy to 650 psi/10 min. Rig down test equip. 19:30 19:45 0.25 4,335 4,335 PROD4 WHPST CIRC P Obtain SPR's @ 4335'MD.3080' TVD. 10.2 ppg MW. 19:30 hrs. #1 30spm= 120 psi 40spm =180 psi #2 30spm=120 psi 40spm =180 psi 19:45 00:00 4.25 4,335 4,360 PROD4 WHPST MILL P Mill window in 9 5/8"casing f/4346' • MD t/4360'MD 3074'TVD 450 gpm, 1100 psi, 80 rpm,Tq on 7-10K, Tq off 4K, PU 110K, SO 98K, Rot 108K, FO 48% OA=205 psi 35/14/2015 Finish milling window to 4363'MD. Drilled new hole to 4385'MD. Dress window, pump sweep. Perform FIT to 13.6 ppg EMW. OWFF. Pump out of hole as per schedule to 2319'MD.POH on elevators to 449'MD. Lay down BHA. Flush BOPE. Change over to 4"handling equip.Make up cleanout BHA.TIH. Drill to 4555'MD'. Pump out of hole to 4320'MD. CBU. OWFF. Pump out of hole to 3941'MD. 00:00 00:45 0.75 4,360 4,363 PROD4 WHPST MILL P Cont. milling window f/4360'to 4363' @450gpm @1100psi w/2to4K WOB 00:45 01:45 1.00 4,363 4,385 PROD4 WHPST DDRL P Drilled 22'new hole f/4363'to 4385' MD 8 to 15 k WOB 450 gpm @ 1100 psi 01:45 03:00 1.25 4,385 4,385 PROD4 WHPST REAM P Dress window-Pumped 30 bbls Hi-Vis sweep-slide thru window w/ pump&without pump(No Problem Recovered 217 lbs of metal collected f/magnets 03:00 04:00 1.00 4,385 4,330 PROD4 WHPST FIT P Pulled back to 4330'MD(stood back 1 std DP)-RU&performed FIT to 13.6 ppg EMW-RD test equipment- Blow down lines 04:00 04:30 0.50 4,330 4,330 PROD4 WHPST OWFF P Monitor well -static Obtain SPR's @ 0430 hr. @ 4335' MD 3080'TVD w/10.1 ppg mud #1 30/40 SPM 100/160 psi #2 30/40 SPM 95/145 psi Page 52 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:30 3.00 4,330 2,319 PROD4 WHPST PMPO P PJSM-POOH w/pump f/4330'to 2319'@ 3 bbls/min @ 150 psi-PU wt 110 SO wt. 98 Calc fill 17.1 bbls-Actual fill 17.4 bbls 07:30 08:30 1.00 2,319 449 PROD4 WHPST TRIP P POOH on elevators f/2319'to 449' Calc fill 28 bbls-Actual fill 29.5 bbls 08:30 10:15 1.75 449 0 PROD4 WHPST BHAH P PJSM-LD milling assembly-5" HWDP- 6 3/4"DC's-XO- Telescope-OX-float sub-5"HWDp (1 jt)upper mill-flex jt-lower mill- starter mill 10:15 11:15 1.00 0 0 PROD4 WHPST WWWH P MU stack washer-function annular, upper&lower pipe rams &blid rams - Flush stack©650 gpm 11:15 14:30 3.25 0 0 PROD4 WHPST RURD P PJSM-Change saver sub in TD f/4 1/2"IF to 4"XT-39-Change handling tools for 4' DP 14:30 15:00 0.50 0 0 PROD4 WHPST SVRG P Service rig. 15:00 17:00 2.00 0 351 PROD4 WHPST BHAH P PJSM-Pick up clean out BHA as per SLB reps. 17:00 17:30 0.50 351 1,487 PROD4 WHPST TRIP P PJSM-RIH f/351'MD t/1487'MD. 17:30 17:45 0.25 1,487 1,487 PROD4 WHPST DHEQ P Shallow hole test MWD. 220 gpm, 1400 psi,20 rpm,tq 2-3K, FO 44% 17:45 19:00 1.25 1,487 4,320 PROD4 WHPST TRIP P RIH f/1487'MD t/4320'MD. 19:00 19:15 0.25 4,320 4,385 PROD4 WHPST WASH P Wash down f/4320' MD t/4346'MD. 220 gpm, 1500 psi. Orient motor to highside,shut down pumps and slide through window f/4346'MD t/4363' MD. Resume pumping and RIH t/4385'MD 19:15 21:30 2.25 4,385 4,555 PROD4 DRILL DDRL P DDrilg, f/4385't/4555'MD,TVD= 3712',AST=1.05 ADT=1.54 Bit= 4.09, Jars= 103.70, PU=95K, SO =71K, ROT=86K,Tq on 3-4K, off 2K, FO 40%,WOB= 10-15K, 50 rpm,220 gpm, 1800 psi, Max Gas= 40 units. SPR's @ 4552'MD, 3695'TVD, MW 10.2 ppg,21:30 hrs. #1 @ 20=380©30=620 #2 @ 20=380 @ 30=680 21:30 22:00 0.50 4,555 4,320 PROD4 DRILL PMPO P Pump out of hole f/4555'MD t/4370' MD. 220 gpm, 1700 psi. Shut down pumps,slowly pull through window f/4363'MD V 4346'MD. No problems observed. Pull up t/4320'MD 22:00 23:00 1.00 4,320 4,320 PROD4 DRILL CIRC P CBU. 220 gpm, 1700 psi. Rotate and reciprocate @ 50 rpm w/2K tq. FO 40% 23:00 23:30 0.50 4,320 4,320 PROD4 DRILL OWFF P OWFF. Static. Page 53 of 70 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 4,320 3,941 PROD4 DRILL PMPO P Pump out of hole f/4320'MD t/3941' MD.3 bpm, 650 psi. Calc disp=3.24 bbls Act disp=4.2 bbls OA=180 psi 35/15/2015 Cont. POOH w/pump to 3846'-Flow ck(static)POOH on elevators to 351'-LD motor assembly(clean out assembly)-Function all rams&flush stack-RU&Test BOPE.. RD and clear floor. Service rig. Make up BHA#28. Repair iron roughneck. 00:00 00:30 0.50 3,941 3,846 PROD4 DRILL TRIP P PJSM-Cont. POOH w/pump f/ 3941'to 3846'@ 3 bbls/min @ 650 psi-Blow down TD 00:30 00:45 0.25 3,846 3,846 PROD4 DRILL OWFF P Flow ck(static)POOH on elevators f/ 3846'to 351'(top of BHA) 00:45 02:30 1.75 3,846 351 PROD4 DRILL TRIP P POOH on elevators f/3846'to 351' (top of BHA) 02:30 03:00 0.50 351 336 PROD4 DRILL BHAH P Clean&LD Xo's&String magnet to 336' 03:00 04:30 1.50 336 0 PROD4 DRILL BHAH P Pull&stand back HWDP,Jars, & NM flex Dc's-LD Impulse, XO,motor,&bit 04:30 05:00 0.50 0 0 PROD4 DRILL BHAH P Clean up rig floor-Clear floor of BHA tools 05:00 05:30 0.50 0 0 PROD4 WHDBO RURD P RU&pull wear bushing 05:30 06:30 1.00 0 0 PROD4 WHDBO RURD P MU stacke wash&flush stack- Function all rams-LD stack washer 06:30 06:45 0.25 0 0 PROD4 WHDBO RURD P Set test plug 06:45 08:15 1.50 0 0 PROD4 WHDBO RURD P RU test equipment-fill stack& choke manifold w/water 08:15 09:45 1.50 0 0 PROD4 WHDBO RURD T Attempt body test on BOP stack- observed trickle of water leaking past test plug out IA-Pulled test plug- drain stack -Change seal on test plug&reinstall test plug-fill stack- Performed body test OK 09:45 17:15 7.50 0 0 PROD4 WHDBO BOPE P Tested BOPE as follows:annular- upper&lower VBR's-blind rams- choke manifold valves-Choke&kill line valves-4"Demco valve on kill line-TD IBOP's-floor safety&dart valves(4"&5")to 250&3500 psi for 5 mins. -Tested annular&VBRs w/ 5"-4"&4 1/2"test jts. Performed 1500 psi drawdown test on manual and hydraulic chokes Performed accumulator recovey test -Beginning pressure 2975 psi- Pressure after closing 1875 psi- Attained 200 psi in 40 secs. back to full charge in 150 secs. -N2 bottles 2050 psi Witnessing of test waived by Johnny Hill AOGCC 17:15 18:15 1.00 0 0 PROD4 WHDBO RURD P Rig down test equip. Set wear ring. Sim-ops/Change out top drive link tilt spool valve. Page 54 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 18:45 0.50 0 0 PROD4 WHDBO RURD P Blow down lines and choke manifold. Sim-ops/Change out top drive link tilt spool valve. 18:45 20:00 1.25 0 0 PROD4 WHDBO RURD P Clean and clear rig floor. . Sim-ops/ Change out top drive link tilt spool valve. 20:00 20:30 0.50 0 0 PROD4 DRILL SVRG P Service rig. . Sim-ops/Change out top drive link tilt spool valve. 20:30 21:00 0.50 0 0 PROD4 DRILL BHAH P Mobilize BHA to rig floor via beaver slide. 21:00 21:15 0.25 0 0 PROD4 DRILL SFTY P PJSM for making up BHA 21:15 23:00 1.75 0 373 PROD4 DRILL BHAH P Make up rotary steerable BHA as per SLB reps. 23:00 00:00 1.00 373 373 PROD4 DRILL RGRP T Repair hydraulic leaks on iron roughneck OA=190 psi X5/16/2015 RIH w/Power drive BHA f/373'to 4342-Slide thru window @ 4346'to 4363' -MAD pass f/4363' to 4540'- Drill L-3 lateral f/4555'to 5569'MD. 00:00 02:30 2.50 373 4,342 PROD4 DRILL TRIP P RIH w/6 3/4"power drive assembly f/ 373'to 4342'-fill pipe every 20 stds. Calc displacement-26.71 bbls- Actual 24.5 bbls 02:30 02:45 0.25 4,342 4,363 PROD4 DRILL WASH P Slide thru window f/4346'MD to 4363' MD. No issues. 02:45 03:45 1.00 4,363 4,540 PROD4 DRILL DLOG P MADD pass f/4363'MD t/4540'MD. 270 gpm, 2200 psi 03:45 04:00 0.25 4,540 4,555 PROD4 DRILL REAM P Ream to btm f/4540' MD t/4555'MD. 270 gpm, 2200 psi, 10 rpm 04:00 04:30 0.50 4,555 4,555 PROD4 DRILL CIRC P Obtain SPR's-establish drilling parameters-down link SPR's @ 4540'MD 3690'TVD @ 0400 hrs. #1 20/30 SPM 335/565 psi #2 20/30 SPM 325/585 psi 04:30 06:00 1.50 4,555 4,618 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/4555'to 4618'MD 3698'TVD ADT- 1.23 hrs. ECD- 10.57 ppg Footage-63' WOB 2 to 8 k RPM 140 GPM 270 @ 2200 psi w/42%flow out String wt. PU 90 SO 79 ROT 85 Torque on/off btm.-3/1 k ft/lbs Total bit hrs. -70.66 hrs Total jar hrs. 104.93 hrs. Max. gas 367 units Page 55 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 4,618 4,770 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/4618'to 4770'MD 3694'TVD ADT-5.05 hrs ECD-10.53 ppg Footage-152' WOB 2/11 k RPM 140 GPM 270 @ 2200 psi w/40%flow out String wt. PU 89 SO 75 ROT 84 Torque on/off btm.-3/2kftlbs Total bit hrs.75.71 hrs Total jar hrs. 109.98 hrs Max gas 360 units 12:00 18:00 6.00 4,770 5,151 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/4770'to 5151'MD 3698'TVD ADT-4.17 hrs ECD-10.8 ppg Footage-381' WOB 2/5 k RPM 120 GPM 270 @ 2320 psi w/42%flow out String wt. PU 90 SO 74 ROT 80 Torque on/off btm. -3/2kftlbs Total bit hrs.79.88 hrs Total jar hrs. 114.15 hrs Max gas 507 units 18:00 00:00 6.00 5,151 5,569 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/5151'to 5569'MD 3707'TVD ADT-3.99 hrs ECD-10.79 ppg Footage-418' WOB 10/12 k RPM 90 GPM 270 @ 2225 psi w/40%flow out String wt. PU 91 SO 80 ROT 79 Torque on/off btm.-5/2kftlbs Total bit hrs. 83.87 hrs Total jar hrs. 118.14 hrs Max gas 509 units SPR's @ 5568'MD 3704'TVD @ 23:30 hrs. #1 20/30 SPM 340/560 psi #2 20/30 SPM 340/600 psi OA=190 psi 35/17/2015 Drill L-3 lateral w/RSS f/5569'to 6986'MD. Unable to maintain directional control. Circ hi-vis sweep. OWFF. Slight flow.Weight up to 10.3+ppg. OWFF. Static. BROOH f/6989'MD t/6519' MD. Pogo.56 of 70j Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 5,569 6,108 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/5569'to 6108'MD 3713'TVD ADT-4.47 hrs ECD- 11.00 ppg Footage-539' WOB 3 to 11 k RPM 120 GPM 270 @ 2400 psi w/41%flow out String wt. PU 99 SO 69 ROT 84 Torque on/off btm.-4 to5/2 to 3 k ft/lbs Total bit hrs.-88.34 hrs. Total jar hrs. 122.16 hrs Max gas-543 units SPR's @ 6106'MD 3713'TVD w/ 10.2 ppg mud @ 0600 hrs #1 20/30 SPM 400/675 psi #2 20/30 SPM 450/625 psi 06:00 12:00 6.00 6,108 6,660 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/6108'to 6660'MD 3723'TVD ADT-4.53 hrs. ECD- 11.28 ppg Footage-552' WOB 3 to 6 k RPM 140 GPM 270 @ 2700 psi w/41%flow out String wt. PU 98 SO 67 ROT 83 Torque on/off btm.-4/3kft/lbs Total bit hrs. 92.87 hrs Total jar hrs. 127.14 hrs Max gas-885 units SPR's @ 6607'MD 3723'TVD w/ 10.2 ppg mud @ 1130 hrs #1 20/30 SPM 390/660 psi #2 20/30 SPM 400/675 psi 12:00 16:00 4.00 6,660 6,989 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/RSS f/6660' MD to 6989'MD 3722'TVD ADT-2.97 hrs. ECD-11.08 ppg Footage-329' WOB3to5k RPM 70 GPM 270 @ 2500 psi w/41%flow out String wt. PU 96 SO 65 ROT 81 Torque on/off btm.-5/4 k ft/lbs Total bit hrs.95.84 hrs Total jar hrs. 130.11 hrs Max gas-814 units 16:00 16:15 0.25 6,989 6,989 PROD4 DRILL CIRC T Unable to maintain directional control. Confer with rig engineer. Decision made to PON and pick up mud motor. 16:15 17:45 1.50 6,989 6,989 PROD4 DRILL CIRC T Circ. hi-vis sweep.270 gpm,2475 psi, Rot 79K, 120 rpm,4.5K tq, FO 41%. ECD 11.16 ppg. 17:45 18:00 0.25 6,989 6,989 PROD4 DRILL CIRC T Obtain SPR's SPR's @ 6989'MD 3722'TVD w/ 10.2 ppg mud @ 1745 hrs #1 20/30 SPM 420/620 psi #2 20/30 SPM 460/630 psi Page 57 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 6,989 6,989 PROD4 DRILL OWFF T OWFF. Slight flow, slowly diminishing. Decision made to weight up mud to 10.3+ppg. 20:00 22:00 2.00 6,989 6,989 PROD4 DRILL CIRC T Circ and weight up to 10.3+ppg. 270 gpm, 2600 psi, 120 rpm,4K tq, FO 41%ECD=11.25 ppg. 22:00 22:15 0.25 6,989 6,989 PROD4 DRILL CIRC T Obtain SPR's. SPR's @ 6989' MD 3722'TVD w/ 10.3+ppg mud @ 22:00 hrs #2 20/30 SPM 460/630 psi 22:15 22:45 0.50 6,989 6,989 PROD4 DRILL OWFF T OWFF. Static. 22:45 00:00 1.25 6,989 6,519 PROD4 DRILL BKRM T Back ream out of hole f/6989'MD t/6519'MD. 120 rpm,260 gpm,2300 psi,4K tq, ECD=11.17 ppg OA=145 psi. 35/18/2015 Con't to BROOH to window©4346'MD. CBU. OWFF. POH on elevators. LD RSS BHA. PU mud motor BHA.. RIH t/6989'MD. DDrlg L3 lateral.to 7122'MD. 00:00 03:30 3.50 6,519 4,342 PROD4 DRILL BKRM T Cont. BROOH f/6519'to 4342'@ 260 gpm @ 2300 psi w/120 RPM's w/3 to 4 K torque Calc. fill 16.2 bbls Actual 17.5 bbls 03:30 04:15 0.75 4,342 4,342 PROD4 DRILL CIRC T Circ btms up @ 4342'@ 260 gpm @ 1975 psi w/40 rpm's w/2 K torque 04:15 04:45 0.50 4,342 4,342 PROD4 DRILL OWFF T Blow down TD-Monitor well-Static 04:45 07:00 2.25 4,342 372 PROD4 DRILL TRIP T POOH on elevators f/4342'to 372' (Top of BHA)-PU wt 87 SO wt.80 Calc. fill 22.7 bbls actual 27.6 bbls 07:00 07:15 0.25 372 372 PROD4 DRILL OWFF T Monitor well-Static 07:15 09:45 2.50 372 0 PROD4 DRILL BHAH T POOH w/BHA-Stand back HWDP, Jars, & NM flex DC;s-LD Impulse& PeriScope-Surface test Power Drive @ 160 gpm @ 400 psi-LD Power Drive. Calc disp=4.8 bbls Act disp=5.1 bbls 09:45 10:45 1.00 0 0 PROD4 DRILL BHAH T Blow down TD-Clean up&clear rig floor of BHA tools 10:45 12:45 2.00 0 0 PROD4 DRILL SLPC P Slip&cut Drill line 52' 12:45 13:15 0.50 0 0 PROD4 DRILL SVRG P Service draworks&top Drive 13:15 13:45 0.50 0 0 PROD4 DRILL BHAH T Mobilize BHA tools to rig floor 13:45 16:45 3.00 0 380 PROD4 DRILL BHAH T Make up mud motor BHA as per SLB reps. 16:45 17:30 0.75 380 1,516 PROD4 DRILL TRIP T RIH f/380' MD t/1516'MD. 17:30 17:45 0.25 1,516 1,516 PROD4 DRILL DHEQ T Shallow hole test MWD. 210 gpm, 1575 psi, FO 40%. 17:45 19:15 1.50 1,516 4,160 PROD4 DRILL TRIP T RIH f1516'MD t/4160'MD 19:15 19:30 0.25 4,160 4,444 PROD4 DRILL TRIP T Orient tool face 20°left of high side. 220 gpm,2020 psi,40% FO. Slowly RIH thru window. No issues Page 58 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:30 2.00 4,444 6,810 PROD4 DRILL TRIP T RIH f/4444'MD t/6810'MD. Fill pipe every 15 stds. PU 91K, SO 69K. Calc disp=41.88 bbls Act Disp=39.84 bbls 21:30 22:00 0.50 6,810 6,989 PROD4 DRILL REAM T Establish parameters, Ream f6810' MD t/6989'MD. Obtain SPR's. SPR's @ 6889'MD 3722'TVD w/ 10.3+ppg mud @ 21:45 hrs #2 20/30 SPM 600/890 psi 22:00 00:00 2.00 6,989 7,122 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/Steerable Motor f/6989'MD to 7122'MD 3722'TVD ADT-.92 hrs.ART-.45 ECD- 11.14 ppg Footage-133' WOB 1 to 5 k RPM 70 GPM 239 @ 2500 psi w/42%flow out String wt. PU 98 SO 61 ROT 80 Torque on/off btm.-4/3 k ft/lbs Total bit hrs. .92 hrs Total jar hrs. 131.03 hrs Max gas-580 units 05/19/2015 Drilled L-3 lateral w/motor f/7122'MD t/8430'MD. 00:00 06:00 6.00 7,122 7,637 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/7122' to 7637'MD 3732'TVD ATD-5.47 hrs. =ART-2.88 AST- 2.59. ECD-11.29 ppg Footage- 515' WOB 3 to 5 k RPM 56 GPM 240 @ 2600 psi w/42%flow out String wt. PU 97 SO 65 ROT 80 Torque on/off btm.-4/3 k ft/lbs. Total bit hrs.-6.39 hrs. total jar hrs. 135.58 hrs Max Gas 800 units SPR's @ 7280'MD 3721'TVD w/ 10.3+MW@ 0145 hrs #1 20/30 SPM 620/880 psi #2 20/30 SPM 580/890 psi 06:00 12:00 6.00 7,637 7,791 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/7637' to 7791'MD 3740'TVD ADT-4.25 hrs. =ART-3.65 hrs AST.60 hrs ECD-11.40 ppg Footage-154' WOB-3 to 10 k RPM 40 GPM 240 @ 2700 psi w/41%flow out String wt. PU 100 SO 65 ROT 81 Torque on/off btm.-5/3 k ft/lbs Total bit hrs. 10.64 hrs Total jar hrs. 135.58 Max. Gas 662 units SPR's @ 7752'MD 3740'TVD- 10..3+@1130 hrs #1 20/30 SPM 560/890 psi #2 20/30 SPM 560/900 psi Page 59 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 7,791 8,130 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/7791' to 8130'MD 3730'TVD ADT-5.38 hrs. =ART-2.52 hrs AST 2.86 hrs ECD-11.57 ppg Footage-339' WOB-3 to 7 k RPM 40 GPM 233 @ 2600 psi w/42%flow out String wt. PU 97 SO 64 ROT 81 Torque on/off btm.-5/3 k ft/lbs Total bit hrs. 13.90 hrs Total jar hrs. 144.01 Max. Gas 436 units 18:00 00:00 6.00 8,130 8,430 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/8130' to 8430'MD 3734'TVD ADT-3.21 hrs. =ART-2.30 hrs AST.91 hrs ECD-11.28 ppg Footage-300' WOB-5 k RPM 40 GPM 235 @ 2600 psi w/40%flow out String wt. PU 102 SO 59 ROT 80 Torque on/off btm.-5/4 k ft/lbs Total bit hrs. 17.11 hrs Total jar hrs. 147.22 Max. Gas 459 units SPR's @ 8223'MD 3725'TVD- 10..4 @ 19:50 hrs #1 20/30 SPM 660/990 psi #2 20/30 SPM 640/940 psi OA=190 psi 35/20/2015 Drilled L-3 latreal f/8430'MD to 9075'MD Pump hi-vis sweep. OWFF. BROOH to 4538' MD. Open circ sub. CBU x4 @ 550 gpm. Close circ sub. RIH to 7095'MD 00:00 06:00 6.00 8,430 8,792 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/8430' to 8792'MD 3729'TVD ADT-4.51 hrs. =ART-2.64 hrs AST.1.87 hrs ECD-11.52 ppg Footage-362' WOB-5 k RPM 30 GPM 240 @ 2675 psi w/41%flow out String wt. PU 100 SO 60 ROT 82 Torque on/off btm.-5/4 k ft/lbs Total bit hrs.21.62 hrs Total jar hrs. 151.73 Max. Gas 392 units SPR's @ 8789'MD 3728'TVD-10..4 @06:15 hrs #1 20/30 SPM 660/960 psi #2 20/30 SPM 640/940 psi Page 60 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 10:00 4.00 8,792 9,075 PROD4 DRILL DDRL P Drilled 6 3/4"hole w/motor f/8792' to 9075'MD 3738'TVD • ADT-2.88 hrs=ART-1.77 hrs AST-1.87 hrs. ECD-11.74 ppg -Footage-283' WOB3to5k RPM30 GPM240 @ 2710 psi w/40%flow out String wt PU 100 SO 60 ROT 81 Torque on/off btm.-4/4 k ft/lbs Total bit hrs.24.5 hrs Total jars hrs. - 154.61 hrs Max.gas 402 units SPR's 9075'MD 3738'TVD w/10.4 ppg MW @ 1015 hrs. #1 20/30 SPM 625/950 psi #2 20/30 SPM 680/990 psi 10:00 11:00 1.00 9,075 9,075 PROD4 CASING CIRC P Obtain SRP's-Pump Hi-vis sweep @ 240 gpm @ 3000 psi-w/80 rpm's w/4 k torque- ECD 11.78 ppg 11:00 11:15 0.25 9,075 9,075 PROD4 CASING OWFF P Monitor well-Static 11:15 12:00 0.75 9,075 8,701 PROD4 CASING BKRM P BROOH f/9075'to 8701'@ 250 gpm @ 2975 psi w/80 rpm's w/4 k torque -ECD 11.65 ppg Calc. fill 2.1 bbls Actual 8 bbls 12:00 20:30 8.50 8,701 4,538 PROD4 CASING BKRM P BROOH f/8701'to 4538'. Circ sub depth 4343'MD. 250 gpm @ 2200 psi w/80 rpm's w/5 k torque PU 85K SO 75K-ECD Calc. fill=31.67 bbls Actual 57.59 bbls 20:30 20:45 0.25 4,538 4,538 PROD4 CASING CIRC P Establish circulating pressures.2 bpm=450 psi. Drop 1.75"opening ball. Pump down @ 2 bpm. Ball on seat @ 160 stks. Pressure up to 1300 psi and hold for 15 sec's. Observe pressure drop. Circ @ 2 bpm=200 psi. 20:45 22:15 1.50 4,538 4,538 PROD4 CASING CIRC P CBU x4. Stage up pump rate f/230 gpm-500 psi t/600 gpm-2800 psi. 54%FO. Losing mud over shakers. Reduce rate t/550 gpm-2400 psi. 53%FO. Rot 60 rpm, 2K tq, Reciprocate 15'. 22:15 22:30 0.25 4,538 4,538 PROD4 CASING CIRC P Monitor well. Static. Drop 1.75" closing ball. Pump @ 2 bpm, 175 psi, Ball on seat @ 147 stks. Pressure up to 1300 psi. Hold for 30 sec's. Pressure up to 1800 psi. Observe circ sub closure. Confirm closure 2 bpm=450 psi 22:30 00:00 1.50 4,538 7,095 PROD4 CASING TRIP P RIH f/4538'MD t/7095'MD. Cal disp=13.5 bbls Act disp=17.8 bbls. (Had not filled pipe yet.)UP 94K SO 66K. Page 61 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/21/2015 24 hr Summary Cont. RIH f/7095'MD to 8984'MD-Wash down to 9075'-Circ btms up-Change over to SFOBM-POOH w/ pump f/9075'MD t/4349' MD.OWFF. -POOH w/pump f/4349'MD t/3403'MD.POH on elevators f/3403'MD t/380'MD. OWFF. Lay down BHA.Clean and clear rig floor. 00:00 01:15 1.25 7,095 8,984 PROD4 CASING TRIP P RIH f/7095'to 8984' Calc disp.-12.4 bbls-Actual 8.5 bbls 01:15 01:30 0.25 8,984 9,075 PROD4 CASING WASH P Establish circ&wash down f/8984' to 9075'@ 156 gpm @ 1350 psi 01:30 03:30 2.00 9,075 9,075 PROD4 CASING CIRC P Circ btms up @ 240 gpm @ 2750 psi w/80 rpm's w/5 k torque-ECD- 11.36 ppg- 03:30 06:00 2.50 9,075 9,075 PROD4 CASING WAIT T Cont. Circ @ 240 gpm @ 2750 psi w/80 rpm's w/5 k torque while waiting on trucks to load SFOBM @ 1J tank farm and return to rig 06:00 08:15 2.25 9,075 9,075 PROD4 CASING DISP P Displace well f/10.3 ppg Faze-Pro to 10.3 ppg SFOBM as per displacement schedule-250 gpm @ 2800 psi to bit-3500 psi to window @ 4346'-reduce pum,p rate to 200 gpm @ 2800 psi to surface-pumped 580 bbls toatl-ECD-12.20 ppg Obtain SPR's @ 9075'MD 3738' TVD 10.3 ppg MW @ 0800 hrs. #1 10/20 SPM 795/1170 psi #2 10/20 SPM 750/1180 psi 08:15 08:45 0.50 9,075 9,075 PROD4 CASING OWFF P Monitor well-Static 08:45 15:30 6.75 9,075 4,349 PROD4 CASING PMPO P TOOH w/pump f/9075'to 4349'MD @ 3 bbls/min @ 1500 psi Calc. fill 42.2 bbls-Actual fill 52.1 bbls 15:30 16:15 0.75 4,349 4,349 PROD4 CASING OWFF P OWFF. Static 16:15 17:30 1.25 4,349 3,403 PROD4 CASING PMPO P Pump out of hole f/4349'MD t/3403' MD. Blow down top drive Calc. disp=5.4 bbls Act disp=7.35 bbls. 17:30 21:00 3.50 3,403 380 PROD4 CASING TRIP P POH per trip schedule f/3403 t/380' MD. 21:00 21:30 0.50 380 380 PROD4 CASING OWFF P OWFF. Static. Sim-ops/PJSM on laying down BHA 21:30 23:00 1.50 380 0 PROD4 CASING BHAH P Stand back HWDP. Lay down BHA #29 as per SLB reps. Calc disp= 22.43 bbls Act disp=25.1 bbls. 23:00 00:00 1.00 0 0 PROD4 CASING BHAH P Clean and clear rig floor. 35/22/2015 Change pipe handling equipment f/4'to 5'-MU whip stock retrieving BHA-RIH to 4348'-Orient tool to 30 L- engage whip stock&pull free w/150 k-Monitor well(static) Drop bal&open pump out sub-Circ btms. up- Monitor well(static)POOH w/pump 2444'-POOH on elevators f/2444't/110'MD. Lay down whipstock and anchor assy's. Clear rig floor. MU cleanout BHA. RIH to 1473'MD. 00:00 03:00 3.00 0 0 COMPZ CASING RURD P PJSM,CIO saver sub from 4"XT-39 to 5"4-1/2"IF, CIO elevators and lubricate top drive. 03:00 03:30 0.50 0 0 COMPZ CASING BHAH P Mobilize Baker tools to rig floor. Page 62 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:30 2.00 0 110 COMPZ CASING BHAH P M/U whipstock retrieval BHA w/ MWD as per Baker fishing rep. 05:30 06:00 0.50 110 1,500 COMPZ CASING TRIP P RIH w/whipstock retrieval BHA on 5" DP t/1500'MD 06:00 06:15 0.25 1,500 1,500 COMPZ CASING DHEQ P Shallow hole test MWD tools @ 320 gpm=2000 psi,good test 06:15 07:45 1.50 1,500 4,300 COMPZ CASING TRIP P Cont RIH w//whipstock retrieval BHA on 5"DP t/4300' MD. P/U=105K, S/0=94K.Actual displacement=35 bbls, Calculated displacement=35.4 bbls. 07:45 08:15 0.50 4,300 4,306 COMPZ CASING OTHR P Orient retrieval 30L, RIH t/4348'MD, pick up and confirm that whipstock was hooked, P/U to 20K over and bleed jars. P/U to 150K,—45K over and pull anchor free. Cont to pull up to stand one stand back to 4306'- 08:15 08:30 0.25 4,306 4,306 COMPZ CASING OWFF P Monitor well(Static) 08:30 08:45 0.25 4,306 4,306 COMPZ CASING CIRC P Drop 2.5"phenolic ball&pump down @ 2 bbls/min @ 400 psi-shear open Baker shear out sub @ 1700 psi 08:45 09:45 1.00 2,444 COMPZ CASING CIRC P Circ btm up @ 250 gpm @ 600 psi 09:45 10:45 1.00 4,306 4,306 COMPZ CASING OWFF P Monitor well-Static 10:45 14:00 3.25 4,306 2,444 COMPZ CASING PMPO P POOH w/whipstock f/4306'to 2444' w/pump @ 3 bbls/min Calc. fill 21.6 bbls Actual fill-26.6 bbls 14:00 17:00 3.00 2,444 110 COMPZ CASING TRIP P POOH on elevators f/2444'to 110' MD 17:00 19:30 2.50 110 0 COMPZ CASING BHAH P Lay down whipstock retrieving BHA and whipstock anchor BHA as per Baker rep.Clean string magnet below whipstock of metal pieces up to 2"x 3"in size. Calc disp=22.45 bbls Act disp=28.38 bbls. Decision made to perform clean out trip. 19:30 21:00 1.50 0 0 COMPZ CASING BHAH P Clean and clear rig floor. Clean boot baskets 21:00 21:30 0.50 0 0 COMPZ CASING BHAH T Mobilize clean out BHA to rig floor. 21:30 22:45 1.25 0 69 COMPZ CASING BHAH T Make up clean out BHA as per Baker rep. 22:45 00:00 1.25 69 1,473 COMPZ CASING TRIP T RIH f/69'MD t/1473'MD. Calc disp=12.9 bbls Act disp=12.25 PU 60K SO 60K. Fill pipe @ 15 stds. Function test BOPE. J5/23/2015 RIH w/clean out assy.Wash thru MLZXP packer and 4'into SBE. PU above window. CBU. OWFF. POOH as per schedule. Lay do BHA. MU and RIH w/SBD/Anchor assy. Orient and set SBD Top of SBD @ 4340'MD. OWFF. POOH as per schedule. 00:00 01:15 1.25 1,473 4,266 COMPZ CASING TRIP T PJSM, RIH f/1473'MD to 4266'MD. Actual displacement=23.8 bbls, Calculated displacement=24.18 bbls. Page 63 of 70 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:45 0.50 4,266 4,420 COMPZ CASING WASH T Wash down f/4266'MD to 4420'MD, pump @ 2 bpm-325 psi, 18%flow, P/U= 100K, S/O=93K.Tag SBE @ 4420' MD, Cont to circulate and work string twice f/4420'MD to 4390'MD. No problems. 01:45 02:00 0.25 4,420 4,343 COMPZ CASING TRIP T POOH f/4420'MD to 4343'MD 02:00 02:45 0.75 4,343 4,343 COMPZ CASING CIRC T CBU @ 6 bpm=600 psi,20%flow, 20 rpm's=2K Tq.Work pipe f/4343' MD to 4300'MD 02:45 04:00 1.25 4,343 4,343 COMPZ CASING OWFF T OWFF,slight flow to static. 04:00 07:15 3.25 4,343 2,033 COMPZ CASING PMPO T POOH w/pump @ 3 bpm f/4343' MD to 2033'MD. 07:15 08:45 1.50 2,033 69 COMPZ CASING TRIP T POOH on elevators f/2033 MD t/69' MD.calc disp=17.73 bbls Act disp=20.30 bbls 08:45 09:00 0.25 69 69 COMPZ CASING OWFF T OWFF. Static 09:00 10:00 1.00 69 0 COMPZ CASING BHAH T Lay down clean out BHA 10:00 11:30 1.50 0 0 COMPZ CASING BHAH T Clean and clear rig floor. 11:30 13:00 1.50 0 0 COMPZ CASING RURD P Mobilize tools and csg equip to rig floor. Rig up to make up SBD assy. 13:00 15:15 2.25 0 116 COMPZ CASING BHAH P Make up SBD assy.Test FJD release tool as per Baker rep. MU MWD and orient to SBD. 15:15 16:00 0.75 116 1,473 COMPZ CASING RCST P RIH f/116'MD t/1473'MD. 16:00 16:15 0.25 1,473 1,473 COMPZ CASING DHEQ P Shallow hole test MWD. 300 gpm, 575 psi FO 50%. 16:15 17:30 1.25 1,473 4,407 COMPZ CASING RCST P RIH f/1473'MD t/4407'MD. PU 104K, SO 94K, Calc disp=36.35 bbls Act disp=36.15 bbls 17:30 18:15 0.75 4,407 4,340 COMPZ CASING OTHR P PU working single DP. Orient MWD to 60° L, 300 gpm, 1000 psi. RIH and latch into MLZXP packer. Confirmed latch w/40 K overpull twice. Observe tool face rotate to 30° L. Increase pump rate to 500 gpm,2000 psi. PU and release from SBD.Top of SBD @4340'MD 18:15 18:30 0.25 4,340 4,340 COMPZ CASING CIRC P Circulate and wash the inside of the SBD with the FJD tool. Lay down single DP. Blow down top drive. 18:30 20:00 1.50 4,340 4,340 COMPZ CASING OWFF P OWFF. Slight flow to static. Obtain SPR's SPR's @ 4340'MD 3668'TVD 10.4 ppg MW @ 19:45 hrs. #1 20/30 SPM 320/425 psi #2 20/30 SPM 325/440 psi 20:00 23:30 3.50 4,340 1,892 COMPZ CASING PMPO P Pump out of hole(/4430'MD t/1892' MD. 3 bpm,475 psi ICP,275 FCP, FO 25%. Cal disp=20 bbls Act disp=26.6 bbls 23:30 23:45 0.25 1,892 1,892 COMPZ CASING RURD P Blow down top drive. Line up hole fill pump. Page 64 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 1,892 COMPZ CASING TRIP 'P POOH on elevators f/1892'MD t/1611' MD t/1611'MD. Calc disp=2.34 bbls Act disp=7 bbls. 35/24/2015 POOH as per schedule and lay down SBD running tools. Rig up and run 4 1/2' IBT slotted liner to depth. Land and release RAM hanger.TOL @ 4335'MD. PU and run guide nose through SBD and tag no-go. PU and circ to clean SBD. PU above RAM hanger. Displace well to 10.3+brine. OWFF. POOH and lay down liner running tools.Rig up and make up LEM/SLZXP/MWD inner string. RIH to 1556'MD. Shallow hole test MWD. RIH to 2488' MD 00:00 01:15 1.25 1,611 47 COMPZ CASING TRIP P Cont to POOH f/1611'MD to 47' MD, 01:15 01:30 0.25 47 47 COMPZ CASING OWFF P OWFF, static. 01:30 02:15 0.75 47 0 COMPZ CASING BHAH P L/D MWD and Baker FJD running tool as per SLB/Baker rep. Clean and clear rig floor 02:15 03:15 1.00 0 0 COMPZ CASING RURD P Rig up to run 4-1/2"IBTM liner, SIMOPS, mobilize 6-1/8"and 6-1/2" centralizers to rig floor. 03:15 03:30 0.25 0 0 COMPZ CASING SFTY P Hold PJSM on running 4-1/2"liner w/ rig crews, DDI casing and Baker rep, 03:30 07:30 4.00 0 4,712 COMPZ CASING PUTB P RIH w/4-1/2" 11.6#L-80 IBTM liner as per tally to 4712'MD. 07:30 08:15 0.75 4,712 4,712 COMPZ CASING OTHR P M/U Baker RAM liner hanger as per Baker rep. 08:15 08:30 0.25 4,712 4,803 COMPZ CASING RUNL P RIH f/4712'MD t/4803'MD. 08:30 08:45 0.25 4,803 4,803 COMPZ CASING CIRC P Establish parameters. Rot 70K, SO 65K, PU 75K. Pump 10 bbls through liner hanger. 3 bpm, 190 psi, FO 30%. 08:45 11:15 2.50 4,803 9,041 COMPZ CASING RUNL P RIH w/liner on DP f/4803'MD t/9041' MD. Fill every 20 stds. PU 120K, SO 85K. Calc disp=56.35 bbls Act disp=54.5 bbls 11:15 11:30 0.25 9,041 9,041 COMPZ CASING HOSO P Snap in to SBD and set down 20K wt. PU, no overpull observed. Slack off and set 40K down wt. PU and observe 15K overpull confirming latch up. Set down 20K wt.Top of liner @ 4335' MD. Liner depth @ 9041'MD 11:30 12:45 1.25 9,041 4,415 COMPZ CASING HOSO P Drop 29/32"ball. Pump on seat @ 4 bpm, 750 psi. Reduce rate to 3 bpm, 600 psi prior to seating ball. Ball on seat w/791 stks. Pressure up to 500 psi. Pressure up to 2800 psi to release setting tool. PU 7'to confirm release. Pressure up to 4000 psi to attempt to shear out x3. Rig up test pump and shear out ball seat w/4800 psi. 12:45 13:00 0.25 4,415 4,333 COMPZ WELLPF PMPO P Pump out of hole f/4415'MD t/4321' MD. RIH and tag no-go @4335'MD. PU to 4333'MD. PU 108K SO 85K. 13:00 13:45 0.75 4,333 4,333 COMPZ WELLPF OWFF P OWFF. Static. Sim-ops/PJSM on displacing to 10.3+ppg brine Page 65 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 15:15 1.50 4,333 4,290 COMPZ WELLPF DISP P Displace well to 10.3+ppg brine.4 bpm, 550 psi, FO 33%.At 160 bbls pumped increase rate to 6 bpm, 330 psi, FO 53% 15:15 15:30 0.25 4,290 4,290 COMPZ WELLPF CIRC P Obtain SPR's SPR's @ 4333'MD 3668'TVD 10.3 =ppg MW @ 15:15 hrs. #1 40/50 SPM 40/80 psi #2 40/50 SPM 30/70 psi 15:30 16:00 0.50 4,290 4,290 COMPZ WELLPF OWFF P OWFF. Static 16:00 18:45 2.75 4,290 93 COMPZ WELLPF TRIP P Blow down TD. POOH on elevators f/4290'MD t/93'MD 18:45 19:00 0.25 93 0 COMPZ WELLPF BHAH P Lay down running tool.per Baker rep. 19:00 20:00 1.00 0 0 COMPZ WELLPF BHAH P Clean and clear rig floor. Mobilize tools to rig floor. RU to run LEM 20:00 22:15 2.25 0 152 COMPZ RPCOM PUTB P MU LEM/SLZXP BHA as per Baker rep. PU and MU MWD as per SLB rep.Orient LEM to MWD. LEM to MWD offset=296°. Mix and pour pal mix. 22:15 23:00 0.75 152 1,556 COMPZ RPCOM RCST P RIH f/152'MD t/1556'MD. 23:00 23:30 0.50 1,556 1,556 COMPZ RPCOM DHEQ P Shallow hole test MWD. 80 gpm, 250 psi, FO 15% 23:30 00:00 0.50 1,556 2,488 COMPZ RPCOM RCST P RIH w/LEM-SLZXP f/1556' MD t/2488'MD. PU 77K, SO 77K. Calc disp=20.7 bbls Act disp=30.06 bbls. (Pipe not filled for 10 stds.) 05/25/2015 RIH and latch in LEM/SLZXP. Set and test SLZXP packer.OWFF. POOH to 433 MD. Remove super sliders on TOH. Circ out contaminated brine.POOH and lay down running tools and MWD. Rig up and lay down 4" DP. Repair iron roughneck. 00:00 01:00 1.00 2,488 4,350 COMPZ RPCOM RCST P PJSM, Cont to RIH w/LEM/SLZXP on 5" DP f/2488'MD to 4350'MD. Actual displacement= 15.47 bbls, Calculated displacement=15.6 bbls. 01:00 02:00 1.00 4,350 4,362 COMPZ RPCOM PACK P Obtain parameters, P/U=105K, S/O= 96K, orient tool face high side and RIH to 4362'MD,set down 20JK and observed tool face shift to 34°L. P/U 40K over and observed LEM snap out. Set down 20K again, P/U 10K over to confirm latch. Drop 1-1/2"ball and pump down @ 3 bpm=600 psi, slow pumps down to 2 bpm=300 psi, ball on seat @ 567 strokes. Pressure up to 2500 psi, observed packer set, hold for 5 minutes.Walk pressure up to 4000 psi in 500 psi increments. Bleed off pressure and set 20K down, confirm packer is set. P/U and confirm release from SLZXP, Top of SLZXP @ 4220.54'MD 02:00 02:30 0.50 4,362 4,362 COMPZ RPCOM PRTS P R/U and pressure test SLZXP to 3000 psi f/10 minutes by pumping down IA,good test. Page 66 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 02:45 0.25 4,362 4,257 COMPZ RPCOM PMPO P POOH w/pump @ 3 bpm=70 psi, 23%flow f/4362'MD to 4257'MD. Obtain SPR's. 02:45 03:15 0.50 4,257 4,257 COMPZ RPCOM OWFF P OWFF,static. 03:15 05:30 2.25 4,257 433 COMPZ RPCOM TRIP P POOH on elevators removing WWT super sliders f/4257'MD t/433'MD. Calc disp=31.2 bbls Act disp=33.49 bbls. 05:30 07:45 2.25 433 433 COMPZ RPCOM CIRC T Shaker screens blinding off due to migrating OBM. Circ out contaminated brine. Clean under shakers and trip tank. Monitor well. 07:45 08:00 0.25 433 95 COMPZ RPCOM TRIP P POOH on elevators f/433' MD t/95' MD. Calc disp=3.9 bbls Act disp=1.87 bbls. 08:00 09:00 1.00 95 0 COMPZ RPCOM BHAH P Lay down MWD and LEM running tools as per SLB/Baker reps. 09:00 10:00 1.00 0 0 COMPZ RPCOM BHAH P Clean and clear rig floor. Blow down TD and kill line. 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD P Rig up to lay down 4"DP. Change over iron roughneck jaws to 4". Monitor well with trip tank 10:30 14:45 4.25 0 0 COMPZ RPCOM PULD P Lay down 132 Jts.of 4"XT39 DP using mousehole. 14:45 15:15 0.50 0 0 COMPZ RPCOM SVRG P Service rig. 15:15 22:00 6.75 0 0 COMPZ RPCOM PULD P Lay down 264 Jts of 4"XT39 DP using mousehole. 22:00 00:00 2.00 0 0 COMPZ RPCOM RGRP T Repair torque cylinder on upper jaw of iron roughneck. Monitor well w/trip tank. Static 05/26/2015 Finish laying down 4"DP. Rig up and lay down 59 stands of 5" DP. Pull wear bushing. Wash wellhead. Perform tbg hanger dummy run. RU to run 4 1/2' IBTM upper completion. Run upper completion from surface to 4228'MD.Terminated TEC wire at hanger penetration. Rigged up to spot corrosion inhibited brine. 00:00 00:45 0.75 0 0 COMPZ RPCOM PULD P PJSM, lay down 21 jts.of 4"DP. Fire Drill CRT 95 sec @ 00:40 hrs. 00:45 01:00 0.25 0 0 COMPZ RPCOM RURD P PJSM,change out handling equipment f/4"to 5". 01:00 05:00 4.00 0 0 COMPZ RPCOM PULD P PJSM, lay down 177 jts. of 5"DP. 05:00 05:30 0.50 0 0 COMPZ RPCOM RURD P Clear&clean rig floor. 05:30 06:15 0.75 0 0 COMPZ RPCOM WWWH P PJSM,flush stack with washer. 06:15 06:30 0.25 0 0 COMPZ RPCOM RURD P PJSM, pull wear ring as per Vetco. 06:30 07:30 1.00 0 0 COMPZ RPCOM RURD P PJSM, perform dummy run with hanger as per Vetco Rep. 07:30 08:00 0.50 0 0 COMPZ RPCOM RURD P PJSM, rig up casing handling equipment. 08:00 10:30 2.50 0 0 COMPZ RPCOM RURD P PJSM, mobilize Baker tools to rig floor&rig up TEC wire. 10:30 10:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up jewery for 4.5" upper completion run. 10:45 11:00 0.25 0 75 COMPZ RPCOM PUTB P Pick up seal assembly, 1 jt of 4.5" tubing&the Baker guage carrier. 11:00 12:45 1.75 75 75 COMPZ RPCOM PUTB P Make up TEC wire to guage carrier as per Baker Reps. Page 67 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 20:00 7.25 75 4,190 COMPZ RPCOM PUTB P PJSM, pick up 4.5", 12.6#, L-80, IBTM upper completion as per detail from 75'-4190'MD.Installed 106 full clamps&2 bands.Calculated displacement 19.09, actual 18.7 bbls. PU 71K, SO 67K. 20:00 22:00 2.00 4,190 4,228 COMPZ RPCOM HOSO P PJSM, space out running in to 4260' to fully located. Did not observe pressure increase while washing down through seals. Performed 500 psi PT on IA to confirm seal assembly is stabbed into the seal bore. Lay down 3 joints&pick up 9.81'pup. Make up pup,joint 101 & hanger assembly @ 4228'MD. 22:00 23:15 1.25 4,228 4,228 COMPZ RPCOM THGR P PJSM,terminate TEC wire per Vetco &Baker Rep. 23:15 23:45 0.50 4,228 4,228 COMPZ RPCOM RURD P PJSM, rig up circulating equipment to landing joint&make up landing joint to hanger. 23:45 00:00 0.25 4,228 4,228 COMPZ RPCOM RURD P Clear Baker equipment from rig floor. 05/27/2015 Spot corrosion inhibited brine. Land hanger&RILDS. PT hanger seals to 5000 psi. PT IA to 1000 psi. Drop ball&rod. PT tubing to 3500&IA to 3000 psi. Shear SOV. Install TWC valve. PT TWC to 2000 psi in the direction of flow. Nipple down BOPE& NU tree. 00:00 00:30 0.50 4,228 4,228 COMPZ RPCOM RURD P PJSM, rig up&hook up lines. 00:30 01:00 0.50 4,228 4,228 COMPZ RPCOM THGR T PJSM, pump 1 bbl of corrosion inhibited brine¬iced leak at side outlet of hanger. Shut down, remove landing joint, &change out 0-ring. Reinstall landing joint&test seal, good. 01:00 01:15 0.25 4,228 4,228 COMPZ RPCOM CRIH P Pump 38 bbls of Conqor 303A w/ Oxygen Scavenger&biocide brine, chased w/64 bbls of 10.3 ppg brine @ 5 bpm, 300 psi. 01:15 01:45 0.50 4,228 4,228 COMPZ RPCOM OWFF P Monitor well,static. 01:45 02:00 0.25 4,228 4,228 COMPZ RPCOM RURD P PJSM, drain stack, blow down choke &kill lines. 02:00 02:45 0.75 4,228 4,255 COMPZ RPCOM THGR P PJSM, land hanger, &RILDS. 02:45 03:15 0.50 4,255 4,255 COMPZ RPCOM THGR P PJSM,test upper&lower seals to 5000 psi for 15 min.each.Tests witnessed by Co. Man. 03:15 04:00 0.75 4,255 4,255 COMPZ RPCOM PRTS P PJSM, rig up&test IA to 1000 psi for 10 min, charted. 04:00 04:30 0.50 4,255 4,255 COMPZ RPCOM OWFF P Monitor well,static. 04:30 06:00 1.50 4,255 4,255 COMPZ RPCOM PRTS P PJSM,drop 1.875"ball&rod,allow to fall for 10 min. PT tubing to 3500 psi for 30 min charted. Bleed tubing pressure to 2000 psi&shut in. PT IA to 3000 psi for 30 min, charted. Bleed off tubing pressure&observe SOV shear. Both tubing&IA bled to 0 psi. Spill Drill CRT 79 sec @ 05:45 hrs. Page 63 of 70 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 4,255 4,255 COMPZ RPCOM OWFF P Monitor well, static. 06:30 07:00 0.50 4,255 4,255 COMPZ RPCOM RURD P PJSM, rig down test equipment, landing joint,&pump in sub. 07:00 07:30 0.50 4,255 0 COMPZ WHDBO MPSP P PJSM,set TWC valve&test to 2000 psi for 5 min in direction of flow, charted. 07:30 08:00 0.50 0 0 COMPZ WHDBO OWFF P Monitor well,static. SIM/OPS clear rig floor of casing equipment. 08:00 12:00 4.00 0 0 COMPZ WHDBO NUND P PJSM, open ram doors clean& remove rams. SIM/OPS disconnect kill&choke lines. Secure tree out of the way. 12:00 20:00 8.00 0 0 COMPZ WHDBO NUND P PJSM, nipple down stack dropping each component. Remove BOPE yoke. SIM-OPS clean pits/pit room; blow down&disassemble both mud pumps. 20:00 00:00 4.00 0 0 COMPZ WHDBO NUND P PJSM, nipple up tree per Vetco. Terminate TEC wire per Baker Rep. Install 1502 circulating flanges. 05/28/2015 TEC wire damaged while terminating.Trouble shot&discussed with town. Had splice sleeve machined shorter. Made splice between hanger&tree. Nippled up&found splice to long. Decided to machined a shorter splice sleeve.Wait for sleeve to be delivered. SIMOPS clean&prep for rig move. 00:00 01:00 1.00 0 0 COMPZ WHDBO NUND P PJSM,terminate TEC wire as per Baker Rep. SIM-OPS rig up to circulate through choke. 01:00 04:15 3.25 0 0 COMPZ WHDBO NUND T After terminating, TEC wire would not test. Baker Field Service Manager contacted in Anchorage to troubleshoot.Two additional Field Techs. arrived&disassembled termination. Found TEC wire pinched inside termination. 04:15 09:45 5.50 0 0 COMPZ WHDBO WAIT T Confer with town and asset meeting called to decide on path forward. 09:45 16:15 6.50 0 0 COMPZ WHDBO WAIT T Decision made to cut down& machine smaller splice from 6"to 2.5". Part sent to Baker shop. SIMOPS clean pits&rockwasher. Take down stabbing board. C/O oil in rotary table&wash torque tube. 16:15 19:30 3.25 0 0 COMPZ WHDBO NUND T PJSM, nipple down tree. Re Splice TEC wire&lower tree onto wellhead. Splice connection sticking out of penetration to much. Consult with town. 19:30 00:00 4.50 0 0 COMPZ WHDBO WAIT T Decide to cut/machine splice sleeve down from 2.5"&make two more at 1.5"& 1"to fit under bonnet. Splice sleeve sent to Baker machine shop. SIMOPS install nuts on BOPE, remove dutch riser adaper flange from annular, continue cleaning OBM around rig. Page 69 of 70 Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/29/2015 24 hrSummary Splice TEC wire&finish NU tree. PT void&tree to 5000 psi. Remove TWC. Rig up&freeze protect. Set BPV &test in direction of flow. Secure well. Clean rig of OBM&rig down for move to 2S pad. 00:00 00:30 0.50 0 0 COMPZ WHDBO WAIT T Wait on Baker to return with machined splice sleeve. SIMOPS continue cleaning OBM around rig. 00:30 02:45 2.25 0 0 COMPZ WHDBO NUND T PJSM, nipple down tree. Splice TEC wire with 1"machined splice sleeve, tested good. Nipple up tree&retest good. 02:45 04:15 1.50 0 0 COMPZ WHDBO NUND T Terminate TEC wire as per Baker Reps.Tested good. 04:15 04:30 0.25 0 0 COMPZ WHDBO PRTS P PJSM,test void to 5000 psi for 10 min,witnessed by Co. Rep. 04:30 05:00 0.50 0 0 COMPZ WHDBO NUND P PJSM, Remove tree cap&fill with diesel. Rig up to test tree. 05:00 05:15 0.25 0 0 COMPZ WHDBO PRTS P PJSM,pressure test tree to 5000 psi for 10 min,witnessed by Co. Rep. 05:15 05:30 0.25 0 0 COMPZ WHDBO MPSP P PJSM, pull TWC valve. 05:30 06:00 0.50 0 0 COMPZ WHDBO FRZP P PJSM, rig up to freeze protect well. 06:00 08:00 2.00 0 0 COMPZ WHDBO FRZP P PJSM, pump 150 bbls of diesel down the IA,taking returns from the tubing @ 2 bpm, 500 psi, FCP 2000 psi. 148 bbls returns, SITP 0 psi, IA pressure 650 psi. 08:00 09:30 1.50 0 0 COMPZ WHDBO FRZP P PJSM, U-tube freeze protect in well. SIMOPS remove kill&choke line. 09:30 10:45 1.25 0 0 COMPZ WHDBO MPSP P PJSM, pick up&rig up lubricator. 10:45 11:30 0.75 0 0 COMPZ WHDBO MPSP P PJSM, set 4",type H BPV as per Vetco Rep. 11:30 11:45 0.25 0 0 COMPZ WHDBO MPSP P PJSM,test BPV in direction of flow for 5 min,good. 11:45 12:45 1.00 0 0 DEMOB MOVE RURD P PJSM, blow down lines&secure well. 12:45 18:00 5.25 0 0 DEMOB MOVE RURD P PJSM, remove scaffolding,clean pit #6, clean rig floor, &under floor. Clean rock washer to move. Clean handling equipment&remove from rig floor. 18:00 00:00 6.00 0 0 DEMOB MOVE RURD P PJSM, clean top drive, rig floor mats, cattle chute, Iron Roughneck, sub rack, under rotary table, & drawworks brake linkage. IA pressure 1600 psi @ 24:00 hrs Rig Release @ 24:00 hrs. Page 70 of 70 • • NADConversion Kuparuk River Unit Kuprauk 1D Pad 1 D-1 43L3 Definitive Survey Report 28 May, 2015 —� • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1 D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1D-143 Well Position +N1-S 0.00 usft Northing: 5,959,384.08 usft Latitude: 70°17'58.542 N +El-W 0.00 usft Easting: 560,670.58 usft Longitude: 149°30'31.113 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 66.90 usft Wellbore 1D-143L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 5/15/2015 18.94 80.92 57,563 Design 1D-143L3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,335.19 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.24 0.00 0.00 0.00 Survey Program Date 5/28/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 85.00 1,675.00 1 D-143 Srvy#1 GYD GYD-GC-MS(1 D- GYD-GC-SS Gyrodata gyro single shots 3/30/2015 3:57: 1,704.17 2,428.24 1D-143 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/31/2015 2:15: 2,473.31 2,473.31 1D-143 Srvy#3 INC+TREND(1D-143) INC+TREND Inclinometer+known azi trend 4/5/2015 3:09:0 2,567.32 4,335.19 1D-143 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/13/2015 11:07: 4,346.00 4,373.31 1D-143L3 Srvy#1 INC+TREND(1D-143 INC+TREND Inclinometer+known azi trend 5/9/2015 4:16:0 4,467.75 9,008.13 1D-143L3 Srvy#2 MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/26/2015 4:03: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section 1 (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.24 0.00 0.00 27.24 -66.90 0.00 0.00 5,959,384.08 560,670.58 0.00 0.00 UNDEFINED 85.00 0.23 183.60 85.00 -9.14 -0.12 -0.01 5,959,383.97 560,670.57 0.40 -0.12 GYD-GC-SS(1) 185.00 0.33 177.70 185.00 90.86 -0.60 -0.01 5,959,383.48 560,670.57 0.10 -0.60 GYD-GC-SS(1) 278.00 0.28 160.86 278.00 183.86 -1.09 0.08 5,959,383.00 560,670.66 0.11 -1.09 GYD-GC-SS(1) 370.00 0.53 169.94 369.99 275.85 -1.72 0.22 5,959,382.37 560,670.81 0.28 -1.72 GYD-GC-SS(1) 462.00 0.76 119.33 461.99 367.85 -2.44 0.83 5,959,381.66 560,671.43 0.64 -2.44 GYD-GC-SS(1) 555.00 1.42 107.85 554.97 460.83 -3.09 2.47 5,959,381.01 560,673.07 0.74 -3.09 GYD-GC-SS(1) 646.00 2.48 101.80 645.92 551.78 -3.84 5.47 5,959,380.29 560,676.07 1.18 -3.84 GYD-GC-SS(1) 740.00 3.54 100.64 739.79 645.65 -4.79 10.31 5,959,379.38 560,680.92 1.13 -4.79 GYD-GC-SS(1) 835.00 4.86 107.55 834.53 740.39 -6.55 17.03 5,959,377.68 560,687.66 1.49 -6.55 GYD-GC-SS(1) 5/28/2015 10:12:23AM Page 2 COMPASS 5000.1 Build 65 II i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 930 00 7.22 113.31 929.00 834.86 -10.12 26.35 5,959,374.18 560,697.00 2 56 -10.12 GYD-GC-SS(1) 1,023.00 9.14 120.91 1,021.05 926.91 -16.23 38.06 5,959,368.16 560,708.76 2.37 -16.23 GYD-GC-SS(1) 1,116.00 9.39 121.22 1,112.84 1,018.70 -23.96 50.88 5,959,360.54 560,721.64 0.27 -23.96 GYD-GC-SS(1) 1,209.00 11.23 117.87 1,204.33 1,110.19 -32.12 65.38 5,959,352.49 560,736.20 2.08 -32.12 GYD-GC-SS(1) 1,301.00 13.25 113.09 1,294.24 1,200.10 -40.45 83.00 5,959,344.31 560,753.89 2.45 -40.45 GYD-GC-SS(1) 1,394.00 12.80 111.65 1,384.85 1,290.71 -48.43 102.38 5,959,336.49 560,773.33 0.60 -48.43 GYD-GC-SS(1) 1,488.00 10.87 106.35 1,476.85 1,382.71 -54.76 120.56 5,959,330.30 560,791.56 2.35 -54.76 GYD-GC-SS(1) 1,582.00 9.49 100.05 1,569.37 1,475.23 -58.61 136.70 5,959,326.58 560,807.73 1.88 -58.61 GYD-GC-SS(1) 1,675.00 8.78 97.39 1,661.19 1,567.05 -60.86 151.29 5,959,324.45 560,822.33 0.89 -60.86 GYD-GC-SS(1) 1,704.17 8.51 101.80 1,690.03 1,595.89 -61.59 155.61 5,959,323.76 560,826.66 2.45 -61.59 MWD+IFR-AK-CAZ-SC(2) 1,797.38 8.29 101.06 1,782.24 1,688.10 -64.29 168.95 5,959,321.17 560,840.02 0.26 -64.29 MWD+IFR-AK-CAZ-SC(2) 1,889.57 8.20 99.89 1,873.47 1,779.33 -66.69 181.95 5,959,318.87 560,853.04 0.21 -66.69 MWD+IFR-AK-CAZ-SC(2) 1,982.54 9.65 97.80 1,965.32 1,871.18 -68.89 196.20 5,959,316.79 560,867.31 1.60 -68.89 MWD+IFR-AK-CAZ-SC(2) 2,075.56 10.45 95.45 2,056.91 1,962.77 -70.75 212.33 5,959,315.06 560,883.45 0.97 -70.75 MWD+IFR-AK-CAZ-SC(2) 2,169.03 10.68 86.92 2,148.80 2,054.66 -71.09 229.41 5,959,314.86 560,900.53 1.69 -71.09 MWD+IFR-AK-CAZ-SC(2) 2,261.50 12.08 70.25 2,239.47 2,145.33 -67.36 247.08 5,959,318.73 560,918.17 3.85 -67.36 MWD+IFR-AK-CAZ-SC(2) 2,355.20 12.67 61.77 2,331.00 2,236.86 -59.18 265.37 5,959,327.05 560,936.38 2.04 -59.18 MWD+IFR-AK-CAZ-SC(2) 2,428.24 14.14 53.03 2,402.06 2,307.92 -50.03 279.55 5,959,336.32 560,950.50 3.42 -50.03 MWD+IFR-AK-CAZ-SC(2) 2,473.31 14.70 47.00 2,445.71 2,351.57 -42.82 288.13 5,959,343.60 560,959.02 3.55 -42.82 INC+TREND(3) 2,489.00 14.90 4544 2,460.88 2,366.74 -40.04 291.03 5,959,34640 560,961 89 2.85 -40.04 MWD+IFR-AK-CAZ-SC(4) 13-318"x 16" 2,567.32 16.06 38.30 2,536.36 2,442.22 -24.47 304.92 5,959,362.08 560,975.65 2.85 -24.47 MWD+IFR-AK-CAZ-SC(4) 2,658.67 16.22 31.87 2,624.12 2,529.98 -3.72 319.49 5,959,382.94 560,990.05 1.96 -3.72 MWD+IFR-AK-CAZ-SC(4) 2,751.79 16.87 24.51 2,713.40 2,619.26 19.62 331.96 5,959,406.38 561,002.34 2.35 19.62 MWD+IFR-AK-CAZ-SC(4) 2,844.45 19.53 13.18 2,801.44 2,707.30 46.95 341.08 5,959,433.78 561,011.23 4.77 46.95 MWD+IFR-AK-CAZ-SC(4) 2,937.25 24.32 2.39 2,887.54 2,793.40 81.18 345.41 5,959,468.04 561,015.29 6.73 81.18 MWD+IFR-AK-CAZ-SC(4) 3,028.68 28.22 359.33 2,969.51 2,875.37 121.62 345.95 5,959,508.48 561,015.50 4.51 121.62 MWD+IFR-AK-CAZ-SC(4) 3,121.99 31.82 359.26 3,050.29 2,956.15 168.29 345.37 5,959,555.14 561,014.54 3.86 168.29 MWD+IFR-AK-CAZ-SC(4) 3,216.24 36.02 359.66 3,128.48 3,034.34 220.87 344.89 5,959,607.71 561,013.63 4.46 220.87 MWD+IFR-AK-CAZ-SC(4) 3,309.85 41.56 357.99 3,201.42 3,107.28 279.48 343.63 5,959,666.30 561,011.91 6.02 279.48 MWD+IFR-AK-CAZ-SC(4) 3,403.28 45.83 358.34 3,268.96 3,174.82 343.97 341.57 5,959,730.77 561,009.33 4.58 343.97 MWD+IFR-AK-CAZ-SC(4) 3,496.85 49.62 357.14 3,331.89 3,237.75 413.14 338.82 5,959,799.90 561,006.02 4.16 413.14 MWD+IFR-AK-CAZ-SC(4) 3,589.95 54.86 354.62 3,388.89 3,294.75 486.51 333.48 5,959,873.22 561,000.08 6.02 486.51 MWD+IFR-AK-CAZ-SC(4) 3,682.45 56.23 353.25 3,441.22 3,347.08 562.35 325.41 5,959,948.99 560,991.41 1.92 562.35 MWD+IFR-AK-CAZ-SC(4) 3,775.57 59.91 353.27 3,490.46 3,396.32 640.82 316.14 5,960,027.37 560,981.50 3.95 640.82 MWD+IFR-AK-CAZ-SC(4) 3,867.74 64.57 354.65 3,533.38 3,439.24 721.91 307.58 5,960,108.38 560,972.29 5.23 721.91 MWD+IFR-AK-CAZ-SC(4) 3,960.92 69.62 352.31 3,569.64 3,475.50 807.14 297.81 5,960,193.53 560,961.83 5.89 807.14 MWD+IFR-AK-CAZ-SC(4) 4,053.13 74.63 349.53 3,597.94 3,503.80 893.76 283.93 5,960,280.02 560,947.26 6.14 893.76 MWD+IFR-AK-CAZ-SC(4) 4,147.42 73.78 349.51 3,623.61 3,529.47 982.98 267.43 5,960,369.09 560,930.04 0.90 982.98 MWD+IFR-AK-CAZ-SC(4) 4,240.13 78.36 348.24 3,645.92 3,551.78 1,071.24 250.06 5,960,457.21 560,911.96 5.12 1,071.24 MWD+IFR-AK-CAZ-SC(4) 5/28/2015 10:12:23AM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,335 19 79.19 347.79 3,664.42 3,570.28 1162.45 230.70 5,960,548.25 560,891.86 0.99 1.162.45 MWD+IFR-AK-CAZ-SC(4) 9 5/8"x12-1/4 4,346.00 78.94 347.89 3,666.47 3,572.33 1,172.83 228.47 5,960,558.60 560,889.54 2.48 1,172.83 INC+TREND(5) 4,363.00 80.60 346.60 3,669.49 3,575.35 1,189.14 224.77 5,960,574.89 560,885.72 12.29 1,189.14 INC+TREND(5) 4,373.31 80.43 346.60 3,671.19 3,577.05 1,199.03 222.42 5,960,584.76 560,883.28 1.65 1,199.03 INC+TREND(5) 4,467.75 84.51 347.27 3,683.57 3,589.43 1,290.22 201.26 5,960,675.76 560,861.39 4.38 1,290.22 MWD+IFR-AK-CAZ-SC(6) 4,560.28 88.67 345.18 3,689.07 3,594.93 1,379.90 179.27 5,960,765.25 560,838.68 5.03 1,379.90 MWD+IFR-AK-CAZ-SC(6) 4,655.77 88.41 345.12 3,691.50 3,597.36 1,472.17 154.80 5,960,857.32 560,813.47 0.28 1,472.17 MWD+IFR-AK-CAZ-SC(6) 4,750.68 90.30 346.50 3,692.57 3,598.43 1,564.17 131.54 5,960,949.12 560,789.47 2.47 1,564.17 MWD+IFR-AK-CAZ-SC(6) 4,846.19 89.59 348.45 3,692.66 3,598.52 1,657.40 110.83 5,961,042.17 560,768.01 2.17 1,657.40 MWD+IFR-AK-CAZ-SC(6) 4,940.69 89.15 351.38 3,693.70 3,599.56 1,750.43 94.28 5,961,135.05 560,750.71 3.14 1,750.43 MWD+IFR-AK-CAZ-SC(6) 5,034.60 88.87 354.45 3,695.32 3,601.18 1,843.60 82.70 5,961,228.11 560,738.38 3.28 1,843.60 MWD+IFR-AK-CAZ-SC(6) 5,129.61 88.77 357.14 3,697.28 3,603.14 1,938.32 75.74 5,961,322.77 560,730.66 2.83 1,938.32 MWD+IFR-AK-CAZ-SC(6) 5,223.02 88.84 358.28 3,699.23 3,605.09 2,031.64 72.01 5,961,416.04 560,726.17 1.22 2,031.64 MWD+IFR-AK-CAZ-SC(6) 5,316.02 88.97 358.60 3,701.01 3,606.87 2,124.58 69.48 5,961,508.96 560,722.89 0.37 2,124.58 MWD+IFR-AK-CAZ-SC(6) 5,412.66 89.33 357.91 3,702.44 3,608.30 2,221.17 66.53 5,961,605.50 560,719.17 0.81 2,221.17 MW1D+IFR-AK-CAZ-SC(6) 5,508.01 88.15 0.61 3,704.54 3,610.40 2,316.48 65.30 5,961,700.79 560,717.17 3.09 2,316.48 MWD+IFR-AK-CAZ-SC(6) 5,602.44 87.98 1.51 3,707.73 3,613.59 2,410.84 67.05 5,961,795.15 560,718.15 0.97 2,410.84 MWD+IFR-AK-CAZ-SC(6) 5,696.43 87.98 1.34 3,711.04 3,616.90 2,504.74 69.38 5,961,889.06 560,719.73 0.18 2,504.74 MWD+IFR-AK-CAZ-SC(6) 5,792.06 89.42 358.85 3,713.21 3,619.07 2,600.33 69.54 5,961,984.64 560,719.11 3.01 2,600.33 MWD+IFR-AK-CAZ-SC(6) 5,885.66 90.67 357.93 3,713.14 3,619.00 2,693.89 66.91 5,962,078.17 560,715.73 1.66 2,693.89 MWD+IFR-AK-CAZ-SC(6) 5,980.00 89.87 357.62 3,712.69 3,618.55 2,788.16 63.25 5,962,172.40 560,711.31 0.91 2,788.16 MWD+IFR-AK-CAZ-SC(6) 6,076.31 88.12 357.74 3,714.38 3,620.24 2,884.37 59.35 5,962,268.57 560,706.63 1.82 2,884.37 MWD+IFR-AK-CAZ-SC(6) 6,170.59 87.81 358.25 3,717.73 3,623.59 2,978.53 56.05 5,962,362.69 560,702.58 0.63 2,978.53 MWD+IFR-AK-CAZ-SC(6) 6,265.05 88.36 357.47 3,720.88 3,626.74 3,072.88 52.53 5,962,456.99 560,698.29 1.01 3,072.88 MWD+IFR-AK-CAZ-SC(6) 6,360.08 89.88 359.03 3,722.34 3,628.20 3,167.84 49.63 5,962,551.92 560,694.62 2.29 3,167.84 MWD+IFR-AK-CAZ-SC(6) 6,454.36 89.83 358.36 3,722.58 3,628.44 3,262.10 47.48 5,962,646.15 560,691.71 0.71 3,262.10 MWD+IFR-AK-CAZ-SC(6) 6,550.39 89.66 359.09 3,723.01 3,628.87 3,358.10 45.34 5,962,742.12 560,688.80 0.78 3,358.10 MWD+IFR-AK-CAZ-SC(6) 6,643.81 90.42 2.10 3,722.94 3,628.80 3,451.51 46.31 5,962,835.52 560,689.02 3.32 3,451.51 MWD+IFR-AK-CAZ-SC(6) 6,738.54 90.11 5.21 3,722.51 3,628.37 3,546.03 52.35 5,962,930.08 560,694.29 3.30 3,546.03 MWD+IFR-AK-CAZ-SC(6) 6,833.62 90.31 7.34 3,722.16 3,628.02 3,640.54 62.74 5,963,024.66 560,703.92 2.25 3,640.54 MWD+IFR-AK-CAZ-SC(6) 6,882.75 89.83 7.17 3,722.10 3,627.96 3,689.27 68.95 5,963,073.44 560,709.73 1.04 3,689.27 MWD+IFR-AK-CAZ-SC(6) 6,928.13 89.97 7.92 3,722.18 3,628.04 3,734.26 74.91 5,963,118.47 560,715.32 1.68 3,734.26 MWD+IFR-AK-CAZ-SC(6) 7,023.47 89.83 7.19 3,722.34 3,628.20 3,828.77 87.44 5,963,213.07 560,727.10 0.78 3,828.77 MWD+IFR-AK-CAZ-SC(6) 7,116.13 89.29 5.69 3,723.05 3,628.91 3,920.84 97.83 5,963,305.21 560,736.74 1.72 3,920.84 MWD+IFR-AK-CAZ-SC(6) 7,212.22 91.12 0.78 3,722.71 3,628.57 4,016.74 103.25 5,963,401.15 560,741.39 5.45 4,016.74 MWD+IFR-AK-CAZ-SC(6) 7,307.04 88.85 358.81 3,722.74 3,628.60 4,111.55 102.92 5,963,495.94 560,740.28 3.17 4,111.55 MWD+IFR-AK-CAZ-SC(6) 7,400.12 88.11 355.67 3,725.21 3,631.07 4,204.48 98.44 5,963,588.82 560,735.06 3.46 4,204.48 MWD+IFR-AK-CAZ-SC(6) 7,494.44 88.41 354.65 3,728.07 3,633.93 4,298.42 90.48 5,963,682.68 560,726.34 1.13 4,298.42 MWD+IFR-AK-CAZ-SC(6) 7,591.31 86.96 353.41 3,731.98 3,637.84 4,394.68 80.42 5,963,778.85 560,715.50 1.97 4,394.68 MVVD+IFR-AK-CAZ-SC(6) 5/28/2015 10:12:23AM Page 4 COMPASS 5000.1 Build 65 0 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,683 38 87.84 354.87 3,736.16 3,642.02 4,486.17 71.03 5,963,870.25 560,705 37 1.85 4,486.17 MWD+IFR-AK-CAZ-SC(6) 7,778.33 89.88 357.23 3,738.05 3,643.91 4,580.86 64.49 5,963,964.88 560,698.07 3.28 4,580.86 MWD+IFR-AK-CAZ-SC(6) 7,873.20 87.92 0.98 3,739.87 3,645.73 4,675.68 63.01 5,964,059.68 560,695.83 4.46 4,675.68 MWD+IFR-AK-CAZ-SC(6) 7,967.37 90.83 2.13 3,740.90 3,646.76 4,769.80 65.56 5,964,153.80 560,697.62 3.32 4,769.80 MWD+IFR-AK-CAZ-SC(6) 8,062.15 93.98 2.08 3,736.92 3,642.78 4,864.42 69.04 5,964,248.44 560,700.33 3.32 4,864.42 MWD+IFR-AK-CAZ-SC(6) 8,156.15 92.36 2.50 3,731.72 3,637.58 4,958.20 72.79 5,964,342.24 560,703.33 1.78 4,958.20 MWD+IFR-AK-CAZ-SC(6) 8,250.76 89.37 7.64 3,730.29 3,636.15 5,052.39 81.15 5,964,436.48 560,710.92 6.28 5,052.39 MWD+IFR-AK-CAZ-SC(6) 8,345.92 88.21 7.70 3,732.30 3,638.16 5,146.67 93.84 5,964,530.85 560,722.86 1.22 5,146.67 MWD+IFR-AK-CAZ-SC(6) 8,440.12 93.10 10.43 3,731.23 3,637.09 5,239.65 108.68 5,964,623.94 560,736.94 5.94 5,239.65 MWD+IFR-AK-CAZ-SC(6) 8,535.29 92.16 12.38 3,726.86 3,632.72 5,332.84 127.48 5,964,717.27 560,754.98 2.27 5,332.84 MWD+IFR-AK-CAZ-SC(6) 8,628.62 88.86 10.88 3,726.03 3,631.89 5,424.24 146.29 5,964,808.80 560,773.05 3.88 5,424.24 MWD+IFR-AK-CAZ-SC(6) 8,722.92 89.26 10.67 3,727.58 3,633.44 5,516.86 163.91 5,964,901.56 560,789.93 0.48 5,516.86 MWD+IFR-AK-CAZ-SC(6) 8,817.05 88.57 10.74 3,729.36 3,635.22 5,609.33 181.40 5,964,994.16 560,806.66 0.74 5,609.33 MWD+IFR-AK-CAZ-SC(6) 8,912.30 87.84 9.84 3,732.34 3,638.20 5,703.00 198.40 5,965,087.96 560,822.91 1.22 5,703.00 MWD+IFR-AK-CAZ-SC(6) 8,960 10 87.74 9.71 3,734 19 3640.05 5,750 08 206.51 5,965,135.09 560,830.64 0.36 5,750.08 MWD+IFR-AK-CAZ-SC(6) 4 1/2"x 6-3/4" 9,008.13 87.63 9.57 3,736.13 3,641.99 5,797.39 214.54 5,965,182.46 560,838.29 0.36 5,797.39 MWD+IFR-AK-CAZ-SC(6) 9075.00 87.63 9.57 3,738.89 3,644.75 5,863.27 225.65 5,965,248.43 560,848.86 0.00 5,863.27 PROJECTED to TD 5/28/2015 10:12:23AM Page 5 COMPASS 5000.1 Build 65 i 0 Cement Detail Report 0 1D-143 Co�n000P'hiIIips String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/28/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/1/2015 19:45 4/1/2015 23:30 1D-143 Comment Line up to SLB.Pump 5 bbls H2O,test lines to 4000 psi. Batch up&pump 75 bbls.of ChemWash @ 5 bpm,225 psi. Batch up&pump 76 bbls 10.5 ppg MudPush @ 5 bpm,225 psi. Drop bottom plug. Batch up&pump 417 bbls of 11.0 ppg Lead cement @ 6.5 bpm,350 psi. Batch up&pump 74 bbls of 12.0 ppg Tail cement @ 6.5 bpm,350 psi. Drop top plug.Pump 10 bbls of H2O @ 5.5 bpm, 150 psi.Line up to rig&displace w/9.5 ppg mud @ 6.5 bpm,400-650 psi, FO 49%. Bump plug w/3440 strokes. Pressure up to 1100 psi&hold for 5 minutes. Bleed off pressure&floats check good.CIP @ 23:30. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 29.0 2,500.0 No 66.0 Yes Yes Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 7 350.0 650.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to SLB.Pump 5 bbls H2O,test lines to 4000 psi. Batch up&pump 75 bbls.of ChemWash @ 5 bpm,225 psi. Batch up&pump 76 bbls 10.5 ppg MudPush @ 5 bpm,225 psi. Drop bottom plug. Batch up&pump 417 bbls of 11.0 ppg Lead cement @ 6.5 bpm,350 psi. Batch up&pump 74 bbls of 12.0 ppg Tail cement @ 6.5 bpm,350 psi.Drop top plug.Pump 10 bbls of H2O @ 5.5 bpm, 150 psi. Line up to rig&displace w/9.5 ppg mud @ 6.5 bpm,400-650 psi, FO 49%. Bump plug w/3440 strokes. Pressure up to 1100 psi&hold for 5 minutes. Bleed off pressure&floats check good.CIP @ 23:30. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 29.0 2,000.0 1,208 G 417.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 67.4 6.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 lbs/bbl Additive Type Concentration Conc Unit label Retarder D110 0.015 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,000.0 2,500.0 253 G 74.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.46 12.00 114.1 4.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 lbs/bbl Additive Type Concentration Conc Unit label Retarder D110 0.015 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Page 1/1 Report Printed: 6/22/2015 • 0 a Cement Detail Report 0 a 1D-143 C.c Phillips '`m String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/28/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/7/2015 21:45 4/8/2015 00:45 1D-143 Comment Line up to SLB cement unit&pump 5 bbls of H2O to test lines.Test lines 250/4000 psi,good.Batch up&pump 50 bbls of 12.0 ppg MudPush©3 bpm, 160 psi. Drop bottom plug. Batch up&pump 90 bbls of 15.8 ppg retarded cement @ 5.4 bpm,260 psi. Batch&pump on the fly 110 bbls of 15.8 ppg GASBLOCK cement ©4.6 bpm,250 psi. Drop top plug. Pump 5 bbls of 12 ppg MudPush&5 bbls of H2O @ 3 bpm, 115 psi.Swap to rig&displace with 10.1 ppg mud @ 5 bpm, 150-720 psi. Reciprocate casing 10-20', Bump plug w/ total of 415 bbls,4118 strokes. Pressure up to 1250 psi&hold for 5 min.Check floats,observe floats not holding. Pressure up to 300 psi to seat plugs&shut in,holding 300 psi.Thickening time for 70 Bc,6:37.CIP 00:45 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 2,860.0 5,725.0 No Yes Yes Cement Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) !Rotated? Pipe RPM(rpm) 3 5 5 720.0 1,250.0 Yes 0.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to SLB cement unit&pump 5 bbls of H2O to test lines.Test lines 250/4000 psi,good. Batch up&pump 50 bbls of 12.0 ppg MudPush @ 3 bpm, 160 psi. Drop bottom plug. Batch up&pump 90 bbls of 15.8 ppg retarded cement @ 5.4 bpm,260 psi.Batch&pump on the fly 110 bbls of 15.8 ppg GASBLOCK cement @ 4.6 bpm,250 psi. Drop top plug. Pump 5 bbls of 12 ppg MudPush&5 bbls of H2O @ 3 bpm, 115 psi.Swap to rig&displace with 10.1 ppg mud @ 5 bpm, 150-720 psi. Reciprocate casing 10-20', Bump plug w/ total of 415 bbls,4118 strokes. Pressure up to 1250 psi&hold for 5 min.Check floats,observe floats not holding.Pressure up to 300 psi to seat plugs&shut in,holding 300 psi.Thickening time for 70 Bc,6:37.CIP 00:45 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 2,860.0 4,117.0 435 G 90.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.05 15.80 76.8 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.05 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 4,117.0 5,725.0 537 G 110.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 4.02 15.80 95.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Page 1/1 Report Printed: 6/22/2015 21 41 48 ` • 1 25911 Schlumberger .UN f Drilling & Measurements Transmittal#: 09JUN15-SP04 DATA LOGGED AOGGMWD/LWD Log Product Delivery K. NDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-143 L3 Date Dispatched: 9-Jun-15 Job#: 14AKA0064 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2 MD x x VISION*Service 2'TVD x x _ VISION*Service 2'TVDSS x x VISION*Service 5'MD x x VISION*Service 5'TVD x x VISION*Service 5'TVDSS x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosoconocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 P2Ag : . .�'Received By: ,t, G /l 2 1 41 68 • • 25911 RECEIVED Transmittal#: 09JUN15-SPO4 SchlumbergerJN 0 9 2015 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 6/25/2015 AOGCC M. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1D-143 L3 Date Dispatched: 9-Jun-15 Job#: 14AKA0064 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 2'TVDSS x x VISION*Service 5" MD x x ^ VISION*Service 5"TVD x x VISION*Service 5'TVDSS x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosoconocophillips.com AlaskaPTSPrintCenter(a�slb.corn Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707o„eve Received By: MALL-02(A.,(17) 214148 • • 25911 Fk‘stw° (310 P FINAL NADConversion Kuparuk River Unit Kuprauk 1D Pad 1D-143L3 Definitive Survey Report NAD 27 28 May, 2015 S 110 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1D-143 Well Position +N/-S 0.00 usft Northing: 5,959,384.08 usft Latitude: 70°17'58.542 N +EI-W 0.00 usft Easting: 560,670.58 usft Longitude: 149°30'31.113 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 66.90 usft Wellbore 1D-143L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 5/15/2015 18.94 80.92 57,563 Design 1D-143L3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,335.19 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (0) 27.24 0.00 0.00 0.00 Survey Program Date 5/28/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 85.00 1,675.00 1D-143 Srvy#1 GYD GYD-GC-MS(1D- GYD-GC-SS Gyrodata gyro single shots 3/30/2015 3:57: 1,704.17 2,428.24 1D-143 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/31/2015 2:15: 2,473.31 2,473.31 1D-143 Srvy#3 INC+TREND(1D-143) INC+TREND Inclinometer+known azi trend 4/5/2015 3:09:0 2,567.32 4,335.19 1D-143 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/13/2015 11:07: 4,346.00 4,373.31 1D-143L3 Srvy#1 INC+TREND(1D-143 INC+TREND Inclinometer+known azi trend 5/9/2015 4:16:0 4,467.75 9,008.13 1D-143L3 Srvy#2 MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/26/2015 4:03: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 27.24 0.00 0.00 27.24 -66.90 0.00 0.00 5,959,384.08 560,670.58 0.00 0.00 UNDEFINED 85.00 0.23 183.60 85.00 -9.14 -0.12 -0.01 5,959,383.97 560,670.57 0.40 -0.12 GYD-GC-SS(1) 185.00 0.33 177.70 185.00 90.86 -0.60 -0.01 5,959,383.48 560,670.57 0.10 -0.60 GYD-GC-SS(1) 278.00 0.28 160.86 278.00 183.86 -1.09 0.08 5,959,383.00 560,670.66 0.11 -1.09 GYD-GC-SS(1) 370.00 0.53 169.94 369.99 275.85 -1.72 0.22 5,959,382.37 560,670.81 0.28 -1.72 GYD-GC-SS(1) 462.00 0.76 119.33 461.99 367.85 -2.44 0.83 5,959,381.66 560,671.43 0.64 -2.44 GYD-GC-SS(1) 555.00 1.42 107.85 554.97 460.83 -3.09 2.47 5,959,381.01 560,673.07 0.74 -3.09 GYD-GC-SS(1) 646.00 2.48 101.80 645.92 551.78 -3.84 5.47 5,959,380.29 560,676.07 1.18 -3.84 GYD-GC-SS(1) 740.00 3.54 100.64 739.79 645.65 -4.79 10.31 5,959,379.38 560,680.92 1.13 -4.79 GYD-GC-SS(1) 835.00 4.86 107.55 834.53 740.39 -6.55 17.03 5,959,377.68 560,687.66 1.49 -6.55 GYD-GC-SS(1) 5/28/2015 10:12:23AM Page 2 COMPASS 5000.1 Build 65 III • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual i 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1D-143 actual©94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 930.00 7.22 113.31 929.00 834.86 -10.12 26.35 5,959,374.18 560,697.00 2.56 -10.12 GYD-GC-SS(1) 1,023.00 9.14 120.91 1,021.05 926.91 -16.23 38.06 5,959,368.16 560,708.76 2.37 -16.23 GYD-GC-SS(1) 1,116.00 9.39 121.22 1,112.84 1,018.70 -23.96 50.88 5,959,360.54 560,721.64 0.27 -23.96 GYD-GC-SS(1) 1,209.00 11.23 117.87 1,204.33 1,110.19 -32.12 65.38 5,959,352.49 560,736.20 2.08 -32.12 GYD-GC-SS(1) 1,301.00 13.25 113.09 1,294.24 1,200.10 -40.45 83.00 5,959,344.31 560,753.89 2.45 -40.45 GYD-GC-SS(1) 1,394.00 12.80 111.65 1,384.85 1,290.71 -48.43 102.38 5,959,336.49 560,773.33 0.60 -48.43 GYD-GC-SS(1) 1,488.00 10.87 106.35 1,476.85 1,382.71 -54.76 120.56 5,959,330.30 560,791.56 2.35 -54.76 GYD-GC-SS(1) 1,582.00 9.49 100.05 1,569.37 1,475.23 -58.61 136.70 5,959,326.58 560,807.73 1.88 -58.61 GYD-GC-SS(1) 1,675.00 8.78 97.39 1,661.19 1,567.05 -60.86 151.29 5,959,324.45 560,822.33 0.89 -60.86 GYD-GC-SS(1) 1,704.17 8.51 101.80 1,690.03 1,595.89 -61.59 155.61 5,959,323.76 560,826.66 2.45 -61.59 MWD+IFR-AK-CAZ-SC(2) 1,797.38 8.29 101.06 1,782.24 1,688.10 -64.29 168.95 5,959,321.17 560,840.02 0.26 -64.29 MWD+IFR-AK-CAZ-SC(2) 1,889.57 8.20 99.89 1,873.47 1,779.33 -66.69 181.95 5,959,318.87 560,853.04 0.21 -66.69 MWD+IFR-AK-CAZ-SC(2) 1,982.54 9.65 97.80 1,965.32 1,871.18 -68.89 196.20 5,959,316.79 560,867.31 1.60 -68.89 MWD+IFR-AK-CAZ-SC(2) 2,075.56 10.45 95.45 2,056.91 1,962.77 -70.75 212.33 5,959,315.06 560,883.45 0.97 -70.75 MWD+IFR-AK-CAZ-SC(2) 2,169.03 10.68 86.92 2,148.80 - 2,054.66 -71.09 229.41 5,959,314.86 560,900.53 1.69 -71.09 MWD+1FR-AK-CAZ-SC(2) 2,261.50 12.08 70.25 2,239.47 2,145.33 -67.36 247.08 5,959,318.73 560,918.17 3.85 -67.36 MWD+IFR-AK-CAZ-SC(2) 2,355.20 12.67 61.77 2,331.00 2,236.86 -59.18 265.37 5,959,327.05 560,936.38 2.04 -59.18 MWD+IFR-AK-CAZ-SC(2) 2,428.24 14.14 53.03 2,402.06 2,307.92 -50.03 279.55 5,959,336.32 560,950.50 3.42 -50.03 MWD+IFR-AK-CAZ-SC(2) 2,473.31 14.70 47.00 2,445.71 2,351.57 -42.82 288.13 5,959,343.60 560,959.02 3.55 -42.82 INC+TREND(3) 2,489.00 14.90 45.44 2,460.88 2,366.74 -40.04 291.03 5,959,346.40 560,961.89 2.85 -40.04 MWD+IFR-AK-CAZ-SC(4) 13-3/8"x 16" 2,567.32 16.06 38.30 2,536.36 2,442.22 -24.47 304.92 5,959,362.08 560,975.65 2.85 -24.47 MWD+IFR-AK-CAZ-SC(4) 2,658.67 16.22 31.87 2,624.12 2,529.98 -3.72 319.49 5,959,382.94 560,990.05 1.96 -3.72 MWD+IFR-AK-CAZ-SC(4) 2,751.79 16.87 24.51 2,713.40 2,619.26 19.62 331.96 5,959,406.38 561,002.34 2.35 19.62 MWD+1FR-AK-CAZ-SC(4) 2,844.45 19.53 13.18 2,801.44 2,707.30 46.95 341.08 5,959,433.78 561,011.23 4.77 46.95 MWD+IFR-AK-CAZ-SC(4) 2,937.25 24.32 2.39 2,887.54 2,793.40 81.18 345.41 5,959,468.04 561,015.29 6.73 81.18 MWD+IFR-AK-CAZ-SC(4) 3,028.68 28.22 359.33 2,969.51 2,875.37 121.62 345.95 5,959,508.48 561,015.50 4.51 121.62 MWD+IFR-AK-CAZ-SC(4) 3,121.99 31.82 359.26 3,050.29 2,956.15 168.29 345.37 5,959,555.14 561,014.54 3.86 168.29 MWD+IFR-AK-CAZ-SC(4) 3,216.24 36.02 359.66 3,128.48 3,034.34 220.87 344.89 5,959,607.71 561,013.63 4.46 220.87 MWD+IFR-AK-CAZ-SC(4) 3,309.85 41.56 357.99 3,201.42 3,107.28 279.48 343.63 5,959,666.30 561,011.91 6.02 279.48 MWD+1FR-AK-CAZ-SC(4) 3,403.28 45.83 358.34 3,268.96 3,174.82 343.97 341.57 5,959,730.77 561,009.33 4.58 343.97 MWD+IFR-AK-CAZ-SC(4) 3,496.85 49.62 357.14 3,331.89 3,237.75 413.14 338.82 5,959,799.90 561,006.02 4.16 413.14 MWD+IFR-AK-CAZ-SC(4) 3,589.95 54.86 354.62 3,388.89 3,294.75 486.51 333.48 5,959,873.22 561,000.08 6.02 486.51 MWD+IFR-AK-CAZ-SC(4) 3,682.45 56.23 353.25 3,441.22 3,347.08 562.35 325.41 5,959,948.99 560,991.41 1.92 562.35 MWD+IFR-AK-CAZ-SC(4) 3,775.57 59.91 353.27 3,490.46 3,396.32 640.82 316.14 5,960,027.37 560,981.50 3.95 640.82 MWD+IFR-AK-CAZ-SC(4) 3,867.74 64.57 354.65 3,533.38 3,439.24 721.91 307.58 5,960,108.38 560,972.29 5.23 721.91 MWD+IFR-AK-CAZ-SC(4) 3,960.92 69.62 352.31 3,569.64 3,475.50 807.14 297.81 5,960,193.53 560,961.83 5.89 807.14 MWD+IFR-AK-CAZ-SC(4) 4,053.13 74.63 349.53 3,597.94 3,503.80 893.76 283.93 5,960,280.02 560,947.26 6.14 893.76 MWD+IFR-AK-CAZ-SC(4) 4,147.42 73.78 349.51 3,623.61 3,529.47 982.98 267.43 5,960,369.09 560,930.04 0.90 982.98 MWD+IFR-AK-CAZ-SC(4) 4,240.13 78.36 348.24 3,645.92 3,551.78 1,071.24 250.06 5,960,457.21 560,911.96 5.12 1,071.24 MWD+IFR-AK-CAZ-SC(4) 5/28/2015 10:12:23AM Page 3 COMPASS 5000.1 Build 65 III III Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,335 19 79.19 347.79 3,664.42 3,570.28 1162.45 230.70 5,960,548.25 560.891 86 0.99 1,162.45 MWD+IFR-AK-CAZ-SC(4) 9 5/8"x 12-1/4 4,346.00 78.94 347.89 3,666.47 3,572.33 1,172.83 228.47 5,960,558.60 560,889.54 2.48 1,172.83 INC+TREND(5) 4,363.00 80.60 346.60 3,669.49 3,575.35 1,189.14 224.77 5,960,574.89 560,885.72 12.29 1,189.14 INC+TREND(5) 4,373.31 80.43 346.60 3,671.19 3,577.05 1,199.03 222.42 5,960,584.76 560,883.28 1.65 1,199.03 INC+TREND(5) 4,467.75 84.51 347.27 3,683.57 3,589.43 1,290.22 201.26 5,960,675.76 560,861.39 4.38 1,290.22 MWD+IFR-AK-CAZ-SC(6) 4,560.28 88.67 345.18 3,689.07 3,594.93 1,379.90 179.27 5,960,765.25 560,838.68 5.03 1,379.90 MWD+IFR-AK-CAZ-SC(6) 4,655.77 88.41 345.12 3,691.50 3,597.36 1,472.17 154.80 5,960,857.32 560,813.47 0.28 1,472.17 MWD+IFR-AK-CAZ-SC(6) 4,750.68 90.30 346.50 3,692.57 3,598.43 1,564.17 131.54 5,960,949.12 560,789.47 2.47 1,564.17 MWD+IFR-AK-CAZ-SC(6) 4,846.19 89.59 348.45 3,692.66 3,598.52 1,657.40 110.83 5,961,042.17 560,768.01 2.17 1,657.40 MWD+IFR-AK-CAZ-SC(6) 4,940.69 89.15 351.38 3,693.70 3,599.56 1,750.43 94.28 5,961,135.05 560,750.71 3.14 1,750.43 MWD+IFR-AK-CAZ-SC(6) 5,034.60 88.87 354.45 3,695.32 3,601.18 1,843.60 82.70 5,961,228.11 560,738.38 3.28 1,843.60 MWD+IFR-AK-CAZ-SC(6) 5,129.61 88.77 357.14 3,697.28 3,603.14 1,938.32 75.74 5,961,322.77 560,730.66 2.83 1,938.32 MWD+IFR-AK-CAZ-SC(6) 5,223.02 88.84 358.28 3,699.23 3,605.09 2,031.64 72.01 5,961,416.04 560,726.17 1.22 2,031.64 MWD+IFR-AK-CAZ-SC(6) 5,316.02 88.97 358.60 3,701.01 3,606.87 2,124.58 69.48 5,961,508.96 560,722.89 0.37 2,124.58 MWD+IFR-AK-CAZ-SC(6) 5,412.66 89.33 357.91 3,702.44 3,608.30 2,221.17 66.53 5,961,605.50 560,719.17 0.81 2,221.17 MWD+IFR-AK-CAZ-SC(6) 5,508.01 88.15 0.61 3,704.54 3,610.40 2,316.48 65.30 5,961,700.79 560,717.17 3.09 2,316.48 MWD+IFR-AK-CAZ-SC(6) 5,602.44 87.98 1.51 3,707.73 3,613.59 2,410.84 67.05 5,961,795.15 560,718.15 0.97 2,410.84 MWD+IFR-AK-CAZ-SC(6) 5,696.43 87.98 1.34 3,711.04 3,616.90 2,504.74 69.38 5,961,889.06 560,719.73 0.18 2,504.74 MWD+IFR-AK-CAZ-SC(6) 5,792.06 89.42 358.85 3,713.21 3,619.07 2,600.33 69.54 5,961,984.64 560,719.11 3.01 2,600.33 MWD+IFR-AK-CAZ-SC(6) 5,885.66 90.67 357.93 3,713.14 3,619.00 2,693.89 66.91 5,962,078.17 560,715.73 1.66 2,693.89 MWD+IFR-AK-CAZ-SC(6) 5,980.00 89.87 357.62 3,712.69 3,618.55 2,788.16 63.25 5,962,172.40 560,711.31 0.91 2,788.16 MWD+IFR-AK-CAZ-SC(6) 6,076.31 88.12 357.74 3,714.38 3,620.24 2,884.37 59.35 5,962,268.57 560,706.63 1.82 2,884.37 MWD+IFR-AK-CAZ-SC(6) 6,170.59 87.81 358.25 3,717.73 3,623.59 2,978.53 56.05 5,962,362.69 560,702.58 0.63 2,978.53 MWD+IFR-AK-CAZ-SC(6) 6,265.05 88.36 357.47 3,720.88 3,626.74 3,072.88 52.53 5,962,456.99 560,698.29 1.01 3,072.88 MWD+IFR-AK-CAZ-SC(6) 6,360.08 89.88 359.03 3,722.34 3,628.20 3,167.84 49.63 5,962,551.92 560,694.62 2.29 3,167.84 MWD+IFR-AK-CAZ-SC(6) 6,454.36 89.83 358.36 3,722.58 3,628.44 3,262.10 47.48 5,962,646.15 560,691.71 0.71 3,262.10 MWD+IFR-AK-CAZ-SC(6) 6,550.39 89.66 359.09 3,723.01 3,628.87 3,358.10 45.34 5,962,742.12 560,688.80 0.78 3,358.10 MWD+IFR-AK-CAZ-SC(6) 6,643.81 90.42 2.10 3,722.94 3,628.80 3,451.51 46.31 5,962,835.52 560,689.02 3.32 3,451.51 MWD+IFR-AK-CAZ-SC(6) 6,738.54 90.11 5.21 3,722.51 3,628.37 3,546.03 52.35 5,962,930.08 560,694.29 3.30 3,546.03 MWD+IFR-AK-CAZ-SC(6) 6,833.62 90.31 7.34 3,722.16 3,628.02 3,640.54 62.74 5,963,024.66 560,703.92 2.25 3,640.54 MWD+IFR-AK-CAZ-SC(6) 6,882.75 89.83 7.17 3,722.10 3,627.96 3,689.27 68.95 5,963,073.44 560,709.73 1.04 3,689.27 MWD+IFR-AK-CAZ-SC(6) 6,928.13 89.97 7.92 3,722.18 3,628.04 3,734.26 74.91 5,963,118.47 560,715.32 1.68 3,734.26 MWD+IFR-AK-CAZ-SC(6) 7,023.47 89.83 7.19 3,722.34 3,628.20 3,828.77 87.44 5,963,213.07 560,727.10 0.78 3,828.77 MWD+IFR-AK-CAZ-SC(6) 7,116.13 89.29 5.69 3,723.05 3,628.91 3,920.84 97.83 5,963,305.21 560,736.74 1.72 3,920.84 MWD+IFR-AK-CAZ-SC(6) 7,212.22 91.12 0.78 3,722.71 3,628.57 4,016.74 103.25 5,963,401.15 560,741.39 5.45 4,016.74 MWD+IFR-AK-CAZ-SC(6) 7,307.04 88.85 358.81 3,722.74 3,628.60 4,111.55 102.92 5,963,495.94 560,740.28 3.17 4,111.55 MWD+IFR-AK-CAZ-SC(6) 7,400.12 88.11 355.67 3,725.21 3,631.07 4,204.48 98.44 5,963,588.82 560,735.06 3.46 4,204.48 MWD+IFR-AK-CAZ-SC(6) 7,494.44 88.41 354.65 3,728.07 3,633.93 4,298.42 90.48 5,963,682.68 560,726.34 1.13 4,298.42 MWD+IFR-AK-CAZ-SC(6) 7,591.31 86.96 353.41 3,731.98 3,637.84 4,394.68 80.42 5,963,778.85 560,715.50 1.97 4,394.68 MWD+IFR-AK-CAZ-SC(6) 5/28/2015 10:12:23AM Page 4 COMPASS 5000.1 Build 65 0 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuprauk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,683.38 87.84 354.87 3,736.16 3,642.02 4,486.17 71.03 5,963,870.25 560,705.37 1.85 4,486.17 MWD+IFR-AK-CAZ-SC(6) 7,778.33 89.88 357.23 3,738.05 3,643.91 4,580.86 64.49 5,963,964.88 560,698.07 3.28 4,580.86 MWD+IFR-AK-CAZ-SC(6) 7,873.20 87.92 0.98 3,739.87 3,645.73 4,675.68 63.01 5,964,059.68 560,695.83 4.46 4,675.68 MWD+IFR-AK-CAZ-SC(6) 7,967.37 90.83 2.13 3,740.90 3,646.76 4,769.80 65.56 5,964,153.80 560,697.62 3.32 4,769.80 MWD+IFR-AK-CAZ-SC(6) 8,062.15 93.98 2.08 3,736.92 3,642.78 4,864.42 69.04 5,964,248.44 560,700.33 3.32 4,864.42 MWD+IFR-AK-CAZ-SC(6) 8,156.15 92.36 2.50 3,731.72 3,637.58 4,958.20 72.79 5,964,342.24 560,703.33 1.78 4,958.20 MWD+IFR-AK-CAZ-SC(6) 8,250.76 89.37 7.64 3,730.29 3,636.15 5,052.39 81.15 5,964,436.48 560,710.92 6.28 5,052.39 MWD+IFR-AK-CAZ-SC(6) 8,345.92 88.21 7.70 3,732.30 3,638.16 5,146.67 93.84 5,964,530.85 560,722.86 1.22 5,146.67 MWD+IFR-AK-CAZ-SC(6) 8,440.12 93.10 10.43 3,731.23 3,637.09 5,239.65 108.68 5,964,623.94 560,736.94 5.94 5,239.65 MWD+IFR-AK-CAZ-SC(6) 8,535.29 92.16 12.38 3,726.86 3,632.72 5,332.84 127.48 5,964,717.27 560,754.98 2.27 5,332.84 MWD+IFR-AK-CAZ-SC(6) 8,628.62 88.86 10.88 3,726.03 3,631.89 5,424.24 146.29 5,964,808.80 560,773.05 3.88 5,424.24 MWD+IFR-AK-CAZ-SC(6) 8,722.92 89.26 10.67 3,727.58 3,633.44 5,516.86 163.91 5,964,901.56 560,789.93 0.48 5,516.86 MWD+IFR-AK-CAZ-SC(6) 8,817.05 88.57 10.74 3,729.36 3,635.22 5,609.33 181.40 5,964,994.16 560,806.66 0.74 5,609.33 MWD+IFR-AK-CAZ-SC(6) 8,912.30 87.84 9.84 3,732.34 3,638.20 5,703.00 198.40 5,965,087.96 560.822.91 1.22 5,703.00 MWD+IFR-AK-CAZ-SC(6) 8,960.10 87.74 9.71 3.734.19 3,640.05 5,750.08 206.51 5,965,135.09 560,830.64 0.36 5,750.08 MWD+IFR-AK-CAZ-SC(6) 4 112"x 6-3/4" 9,008.13 87.63 9.57 3,736.13 3,641.99 5,797.39 214.54 5,965.182.46 560,838.29 0.36 5,797.39 MWD+IFR-AK-CAZ-SC(6) 9,075.00 87.63 9.57 3,738.89 3,644.75 5.863.27 225.65 5,965,248.43 560,848.86 0.00 5,863.27 PROJECTED to TD 5/28/2015 10.12:23AM Page 5 COMPASS 5000.1 Build 65 • • C.) E .w ; \\0L 0\ E\k /} \7 a ! « ± �k/) 8- \ 05 - �)/ > 2 \\\{} 48 Q m49 '- E 0 2 k k k \o 0 / - \ 4 \ < vi 0 II. = a) _\ L. 0 k 0 / 0 CD / 0 f ƒ §¢ � ° § E>NM fri % f § % 0 \ g U 0 \0 a .-6:: / /a) 7 / w 'Ug / / >p m m •.s ea 4= 2 C .� $ t ti m / / \ k D m Ct G 0 m O o m � � � ElElCiE a > m k \ qas 2 a / \ a / W / / 214148 • 2591 r 01" '-0 FINAL \ J ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D-143L3 Definitive Survey Report NAD 83 28 May, 2015 • 0 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual©94.14usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1D-143 Well Position +N/-S 0.00 usft Northing: 5,959,135.59 usft Latitude: 70°17'57.490 N +E/-W 0.00 usft Easting: 1,700,702.54 usft Longitude: 149°30'42.277 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 66.90 usft Wellbore 1D-143L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 5/15/2015 18.94 80.92 57,563 Design 1D-143L3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,335.19 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.24 0.00 0.00 0.00 Survey Program Date 5/28/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 85.00 1,675.00 1D-143 Srvy#1 GYD GYD-GC-MS(1 D- GYD-GC-SS Gyrodata gyro single shots 3/30/2015 3:57: 1,704.17 2,428.24 1D-143 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/31/2015 2:15: 2,473.31 2,473.31 1D-143 Srvy#3 INC+TREND(1D-143) INC+TREND Inclinometer+known azi trend 4/5/2015 3:09:5 2,567.32 4,335.19 1D-143 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/13/2015 11:07: 4,346.00 4,373.31 1D-143L3 Srvy#1 INC+TREND(1D-143 INC+TREND Inclinometer+known azi trend 5/9/2015 4:16:1' 4,467.75 9,008.13 1 D-143L3 Srvy#2 MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/26/2015 4:03: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100'). (ft) Survey Tool Name 27.24 0.00 0.00 27.24 -66.90 0.00 0.00 5,959,135.59 1,700,702.54 0.00 0.00 UNDEFINED 85.00 0.23 183.60 85.00 -9.14 -0.12 -0.01 5,959,135.47 1,700,702.53 0.40 -0.12 GYD-GC-SS(1) 185.00 0.33 177.70 185.00 90.86 -0.60 -0.01 5,959,134.99 1,700,702.54 0.10 -0.60 GYD-GC-SS(1) 278.00 0.28 160.86 278.00 183.86 -1.09 0.08 5,959,134.50 1,700,702.63 0.11 -1.09 GYD-GC-SS(1) 370.00 0.53 169.94 369.99 275.85 -1.72 0.22 5,959,133.87 1,700,702.78 0.28 -1.72 GYD-GC-SS(1) 462.00 0.76 119.33 461.99 367.85 -2.44 0.83 5,959,133.16 1,700,703.39 0.64 -2.44 GYD-GC-SS(1) 555.00 1.42 107.85 554.97 460.83 -3.09 2.47 5,959,132.52 1,700,705.03 0.74 -3.09 GYD-GC-SS(1) 646.00 2.48 101.80 645.92 551.78 -3.84 5.47 5,959,131.80 1,700,708.04 1.18 -3.84 GYD-GC-SS(1) 740.00 3.54 100.64 739.79 645.65 -4.79 10.31 5,959,130.88 1,700,712.89 1.13 -4.79 GYD-GC-SS(1) 835.00 4.86 107.55 834.53 740.39 -6.55 17.03 5,959,129.18 1,700,719.62 1.49 -6.55 GYD-GC-SS(1) 5/28/2015 10:00:57AM Page 2 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1 D-143 Project: Kuparuk River Unit TVD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 1 D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1 D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 930.00 7.22 113.31 929.00 834.86 -10.12 26.35 5,959,125.68 1,700,728.97 2.56 -10.12 GYD-GC-SS(1) 1,023.00 9.14 120.91 1,021.05 926.91 -16.23 38.06 5,959,119.67 1,700,740.72 2.37 -16.23 GYD-GC-SS(1) 1,116.00 9.39 121.22 1,112.84 1,018.70 -23.96 50.88 5,959,112.04 1,700,753.61 0.27 -23.96 GYD-GC-SS(1) 1,209.00 11.23 117.87 1,204.33 1,110.19 -32.12 65.38 5,959,104.00 1,700,768.17 2.08 -32.12 GYD-GC-SS(1) 1,301.00 13.25 113.09 1,294.24 1,200.10 -40.45 83.00 5,959,095.81 1,700,785.85 2.45 -40.45 GYD-GC-SS(1) 1,394.00 12.80 111.65 1,384.85 1,290.71 -48.43 102.38 5,959,087.99 1,700,805.29 0.60 -48.43 GYD-GC-SS(1) 1,488.00 10.87 106.35 1,476.85 1,382.71 -54.76 120.56 5,959,081.80 1,700,823.52 2.35 -54.76 GYD-GC-SS(1) 1,582.00 9.49 100.05 1,569.37 1,475.23 -58.61 136.70 5,959,078.08 1,700,839.69 1.88 -58.61 GYD-GC-SS(1) 1,675.00 8.78 97.39 1,661.19 1,567.05 -60.86 151.29 5,959,075.95 1,700,854.29 0.89 -60.86 GYD-GC-SS(1) 1,704.17 8.51 101.80 1,690.03 1,595.89 -61.59 155.61 5,959,075.26 1,700,858.62 2.45 -61.59 MWD+IFR-AK-CAZ-SC(2) 1,797.38 8.29 101.06 1,782.24 1,688.10 -64.29 168.95 5,959,072.66 1,700,871.99 0.26 -64.29 MWD+IFR-AK-CAZ-SC(2) 1,889.57 8.20 .99.89 1,873.47 1,779.33 -66.69 181.95 5,959,070.36 1,700,885.00 0.21 -66.69 MWD+IFR-AK-CAZ-SC(2) 1,982.54 9.65 97.80 1,965.32 1,871.18 -68.89 196.20 5,959,068.28 1,700,899.27 1.60 -68.89 MWD+IFR-AK-CAZ-SC(2) 2,075.56 10.45 95.45 2,056.91 1,962.77 -70.75 212.33 5,959,066.55 1,700,915.41 0.97 -70.75 MWD+IFR-AK-CAZ-SC(2) 2,169.03 10.68 86.92 2,148.80 2,054.66 -71.09 229.41 5,959,066.35 1,700,932.50 1.69 -71.09 MWD+IFR-AK-CAZ-SC(2) 2,261.50 12.08 70.25 2,239.47 2,145.33 -67.36 247.08 5,959,070.22 1,700,950.13 3.85 -67.36 MWD+IFR-AK-CAZ-SC(2) 2,355.20 12.67 61.77 2,331.00 2,236.86 -59.18 265.37 5,959,078.54 1,700,968.35 2.04 -59.18 MWD+IFR-AK-CAZ-SC(2) 2,428.24 14.14 53.03 2,402.06 2,307.92 -50.03 279.55 5,959,087.81 1,700,982.46 3.42 -50.03 MWD+IFR-AK-CAZ-SC(2) 2,473.31 14.70 47.00 2,445.71 2,351.57 -42.82 288.13 5,959,095.09 1,700,990.98 3.55 -42.82 INC+TREND(3) 2,489.00 14.90 45.44 2,460.88 2,366.74 -40.04 291.03 5,959.097.89 1,700,993.85 2.85 -40.04 MWD+IFR-AK-CAZ-SC(4) 13-3/8"x 16" 2,567.32 16.06 38.30 2,536.36 2,442.22 -24.47 304.92 5,959,113.57 1,701,007.62 2.85 -24.47 MWD+IFR-AK-CAZ-SC(4) 2,658.67 16.22 31.87 2,624.12 2,529.98 -3.72 319.49 5,959,134.43 1,701,022.02 1.96 -3.72 MWD+IFR-AK-CAZ-SC(4) 2,751.79 16.87 24.51 2,713.40 2,619.26 19.62 331.96 5,959,157.87 1,701,034.30 2.35 19.62 MWD+IFR-AK-CAZ-SC(4) 2,844.45 19.53 13.18 2,801.44 2,707.30 46.95 341.08 5,959,185.27 1,701,043.20 4.77 46.95 MWD+IFR-AK-CAZ-SC(4) 2,937.25 24.32 2.39 2,887.54 2,793.40 81.18 345,41 5,959,219.53 1,701,047.26 6.73 81.18 MWD+IFR-AK-CAZ-SC(4) 3,028.68 28.22 359.33 2,969.51 2,875.37 121.62 345.95 5,959,259.97 1,701,047.47 4.51 121.62 MWD+IFR-AK-CAZ-SC(4) 3,121.99 31.82 359.26 3,050.29 2,956.15 168.29 345.37 5,959,306.63 1,701,046.52 3.86 168.29 MWD+IFR-AK-CAZ-SC(4) 3,216.24 36.02 359.66 3,128.48 3,034.34 220.87 344.89 5,959,359.20 1,701,045.61 4.46 220.87 MWD+IFR-AK-CAZ-SC(4) 3,309.85 41.56 357.99 3,201.42 3,107.28 279.48 343.63 5,959,417.79 1,701,043.89 6.02 279.48 MWD+IFR-AK-CAZ-SC(4) 3,403.28 45.83 358.34 3,268.96 3,174.82 343.97 341.57 5,959,482.26 1,701,041.31 4.58 343.97 MWD+IFR-AK-CAZ-SC(4) 3,496.85 49.62 357.14 3,331.89 3,237.75 413.14 338.82 5,959,551.39 1,701,038.00 4.16 413.14 MWD+IFR-AK-CAZ-SC(4) 3,589.95 54.86 354.62 3,388.89 3,294.75 486.51 333.48 5,959,624.71 1,701,032.07 6.02 486.51 MWD+IFR-AK-CAZ-SC(4) 3,682.45 56.23 353.25 3,441.22 3,347.08 562.35 325.41 5,959,700.48 1,701,023.40 1.92 562.35 MWD+IFR-AK-CAZ-SC(4) 3,775.57 59.91 353.27 3,490.46 3,396.32 640.82 316.14 5,959,778.86 1,701,013.50 3,95 640.82 MWD+IFR-AK-CAZ-SC(4) 3,867.74 64.57 354.65 3,533.38 3,439.24 721.91 307.58 5,959,859.87 1,701,004.29 5.23 721.91 MWD+IFR-AK-CAZ-SC(4) 3,960.92 69.62 352.31 3,569.64 3,475.50 807.14 297.81 5,959,945.02 1,700,993.83 5.89 807.14 MWD+IFR-AK-CAZ-SC(4) 4,053.13 74.63 349.53 3,597.94 3,503.80 893.76 283.93 5,960,031.51 1,700,979.27 6.14 893.76 MWD+IFR-AK-CAZ-SC(4) 4,147.42 73.78 349.51 3,623.61 3,529.47 982.98 267.43 5,960,120.59 1,700,962.05 0.90 982.98 MWD+IFR-AK-CAZ-SC(4) 4,240.13 78.36 348.24 3,645.92 3,551.78 1,071.24 250.06 5,960,208.70 1,700,943.98 5.12 1,071.24 MWD+IFR-AK-CAZ-SC(4) 5/28/2015 10:00:57AM Page 3 COMPASS 5000.1 Build 65 0 0 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1 D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,335.19 79.19 347.79 3,664.42 3,570.28 1,162.45 230.70 5,960,299.74 1,700,923.89 0.99 1,162.45 MWD+1FR-AK-CAZ-SC(4) 9 5/8"x 12-1/4 4,346.00 78.94 347.89 3,666.47 3,572.33 1,172.83 228.47 5,960,310.10 1,700,921.57 2.48 1,172.83 INC+TREND(5) 4,363.00 80.60 346.60 3,669.49 3,575.35 1,189.14 224.77 5,960,326.38 1,700,917.74 12.29 1,189.14 1NC+TREND(5) 4,373.31 80.43 346.60 3,671.19 3,577.05 1,199.03 222.42 5,960,336.25 1,700,915.31 1.65 1,199.03 INC+TREND(5) 4,467.75 84.51 347.27 3,683.57 3,589.43 1,290.22 201.26 5,960,427.26 1,700,893.42 4.38 1,290.22 MWD+IFR-AK-CAZ-SC(6) 4,560.28 88.67 345.18 3,689.07 3,594.93 1,379.90 179.27 5,960,516.75 1,700,870.71 5.03 1,379.90 MWD+IFR-AK-CAZ-SC(6) 4,655.77 88.41 345.12 3,691.50 3,597.36 1,472.17 154.80 5,960,608.81 1,700,845.51 0.28 1,472.17 MWD+IFR-AK-CAZ-SC(6) 4,750.68 90.30 346.50 3,692.57 3,598.43 1,564.17 131.54 5,960,700.62 1,700,821.51 2.47 1,564.17 MWD+IFR-AK-CAZ-SC(6) 4,846.19 89.59 348.45 3,692.66 3,598.52 1,657.40 110.83 5,960,793.67 1,700,800.06 2.17 1,657.40 MWD+IFR-AK-CAZ-SC(6) 4,940.69 89.15 351.38 3,693.70 3,599.56 1,750.43 94.28 5,960,886.55 1,700,782.77 3.14 1,750.43 MWD+1FR-AK-CAZ-SC(6) 5,034.60 88.87 354.45 3,695.32 3,601.18 1,843.60 82.70 5,960,979.61 1,700,770.44 3.28 1,843.60 MWD+1FR-AK-CAZ-SC(6) 5,129.61 88.77 357.14 3,697.28 3,603.14 1,938.32 75.74 5,961,074.27 1,700,762.72 2.83 1,938.32 MWD+IFR-AK-CAZ-SC(6) 5,223.02 88.84 358.28 3,699.23 3,605.09 2,031.64 72.01 5,961,167.54 1,700,758.24 1.22 2,031.64 MWD+IFR-AK-CAZ-SC(6) 5,316.02 88.97 358.60 3,701.01 3,606.87 2,124.58 69.48 5,961,260.46 1,700,754.96 0.37 2,124.58 MWD+IFR-AK-CAZ-SC(6) 5,412.66 89.33 357.91 3,702.44 3,608.30 2,221.17 66.53 5,961,357.01 1,700,751.25 0.81 2,221.17 MWD+IFR-AK-CAZ-SC(6) 5,508.01 88.15 0.61 3,704.54 3,610.40 2,316.48 65.30 5,961,452.29 1,700,749.25 3.09 2,316.48 MWD+1FR-AK-CAZ-SC(6) 5,602.44 87.98 1.51 3,707.73 3,613.59 2,410.84 67.05 5,961,546.65 1,700,750.24 0.97 2,410.84 MWD+IFR-AK-CAZ-SC(6) 5,696.43 87.98 1.34 3,711.04 3,616.90 2,504.74 69.38 5,961,640.56 1,700,751.82 0.18 2,504.74 MWD+IFR-AK-CAZ-SC(6) 5,792.06 89.42 358.85 3,713.21 3,619.07 2,600.33 69.54 5,961,736.15 1,700,751.21 3.01 2,600.33 MWD+IFR-AK-CAZ-SC(6) 5,885.66 90.67 357.93 3,713.14 3,619.00 2,693.89 66.91 5,961,829.67 1,700,747.83 1.66 2,693.89 MWD+IFR-AK-CAZ-SC(6) 5,980.00 89.87 357.62 3,712.69 3,618.55 2,788.16 63.25 5,961,923.90 1,700,743.41 0.91 2,788.16 MWD+IFR-AK-CAZ-SC(6) 6,076.31 88.12 357.74 3,714.38 3,620.24 2,884.37 59.35 5,962,020.07 1,700,738.74 1.82 2,884.37 MWD+IFR-AK-CAZ-SC(6) 6,170.59 87.81 358.25 3,717.73 3,623.59 2,978.53 56.05 5,962,114.19 1,700,734.69 0.63 2,978.53 MWD+1FR-AK-CAZ-SC(6) 6,265.05 88.36 357.47 3,720.88 3,626.74 3,072.88 52.53 5,962,208.49 1,700,730.41 1.01 3,072.88 MWD+1FR-AK-CAZ-SC(6) 6,360.08 89.88 359.03 3,722.34 3,628.20 3,167.84 49.63 5,962,303.43 1,700,726.75 2.29 3,167.84 MWD+IFR-AK-CAZ-SC(6) 6,454.36 89.83 358.36 3,722.58 3,628.44 3,262.10 47.48 5,962,397.65 1,700,723.85 0.71 3,262.10 MWD+IFR-AK-CAZ-SC(6) 6,550.39 89.66 359.09 3,723.01 3,628.87 3,358.10 45.34 5,962,493.63 1,700,720.94 0.78 3,358.10 MWD+IFR-AK-CAZ-SC(6) 6,643.81 90.42 2.10 3,722.94 3,628.80 3,451.51 46.31 5,962,587.03 1,700,721.16 3.32 3,451.51 MWD+1FR-AK-CAZ-SC(6) 6,738.54 90.11 5.21 3,722.51 3,628.37 3,546.03 52.35 5,962,681.59 1,700,726.44 3.30 3,546.03 MWD+IFR-AK-CAZ-SC(6) 6,833.62 90.31 7.34 3,722.16 3,628.02 3,640.54 62.74 5,962,776.16 1,700,736.07 2.25 3,640.54 MWD+IFR-AK-CAZ-SC(6) 6,882.75 89.83 7.17 3,722.10 3,627.96 3,689.27 68.95 5,962,824.94 1,700,741.88 1.04 3,689.27 MWD+IFR-AK-CAZ-SC(6) 6,928.13 89.97 7.92 3,722.18 3,628.04 3,734.26 74.91 5,962,869.97 1,700,747.48 1.68 3,734.26 MWD+IFR-AK-CAZ-SC(6) 7,023.47 89.83 7.19 3,722.34 3,628.20 3,828.77 87.44 5,962,964.57 1,700,759.25 0.78 3,828.77 MWD+1FR-AK-CAZ-SC(6) 7,116.13 89.29 5.69 3,723.05 3,628.91 3,920.84 97.83 5,963,056.71 1,700,768.91 1.72 3,920.84 MWD+IFR-AK-CAZ-SC(6) 7,212.22 91.12 0.78 3,722.71 3,628.57 4,016.74 103.25 5,963,152.65 1,700,773.56 5.45 4,016.74 MWD+IFR-AK-CAZ-SC(6) 7,307.04 88.85 358.81 3,722.74 3,628.60 4,111.55 102.92 5,963,247.44 1,700,772.46 3.17 4,111.55 MWD+IFR-AK-CAZ-SC(6) 7,400.12 88.11 355.67 3,725.21 3,631.07 4,204.48 98.44 5,963,340.32 1,700,767.23 3.46 4,204.48 MWD+1FR-AK-CAZ-SC(6) 7,494.44 88.41 354.65 3,728.07 3,633.93 4,298.42 90.48 5,963,434.18 1,700,758.53 1.13 4,298.42 MWD+IFR-AK-CAZ-SC(6) 7,591.31 86.96 353.41 3,731.98 3,637.84 4,394.68 80.42 5,963,530.35 1,700,747.69 1.97 4,394.68 MWD+IFR-AK-CAZ-SC(6) 5/28/2015 10:00:57AM Page 4 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-143 Project: Kuparuk River Unit TVD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: 1D-143 actual @ 94.14usft(Doyon 141) Well: 1D-143 North Reference: True Wellbore: 1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 7,683.38 87.84 354.87 3,736.16 3,642.02 4,486.17 71.03 5,963,621.76 1,700,737.57 1.85 4,486.17 MWD+1FR-AK-CAZ-SC(6) 7,778.33 89.88 357.23 3,738.05 3,643.91 4,580.86 64.49 5,963,716.38 1,700,730.27 3.28 4,580.86 MWD+IFR-AK-CAZ-SC(6) 7,873.20 87.92 0.98 3,739.87 3,645.73 4,675.68 63.01 5,963,811.18 1,700,728.03 4.46 4,675.68 MWD+IFR-AK-CAZ-SC(6) 7,967.37 90.83 2.13 3,740.90 3,646.76 4,769.80 65.56 5,963,905.31 1,700,729.83 3.32 4,769.80 MWD+IFR-AK-CAZ-SC(6) 8,062.15 93.98 2.08 3,736.92 3,642.78 4,864.42 69.04 5,963,999.94 1,700,732.55 3.32 4,864.42 MWD+1FR-AK-CAZ-SC(6) 8,156.15 92.36 2.50 3,731.72 3,637.58 4,958.20 72.79 5,964,093.74 1,700,735.54 1.78 4,958.20 MWD+1FR-AK-CAZ-SC(6) 8,250.76 89.37 7.64 3,730.29 3,636.15 5,052.39 81.15 5,964,187.98 1,700,743.15 6.28 5,052.39 MWD+IFR-AK-CAZ-SC(6) 8,345.92 88.21 7.70 3,732.30 3,638.16 5,146.67 93.84 5,964,282.36 1,700,755.09 1.22 5,146.67 MWD+IFR-AK-CAZ-SC(6) 8,440.12 93.10 10.43 3,731.23 3,637.09 5,239.65 108.68 5,964,375.44 1,700,769.17 5.94 5,239.65 MWD+IFR-AK-CAZ-SC(6) 8,535.29 92.16 12.38 3,726.86 3,632.72 5,332.84 127.48 5,964,468.77 1,700,787.22 2.27 5,332.84 MWD+1FR-AK-CAZ-SC(6) 8,628.62 88.86 10.88 3,726.03 3,631.89 5,424.24 146.29 5,964,560.30 1,700,805.29 3.88 5,424.24 MWD+IFR-AK-CAZ-SC(6) 8,722.92 89.26 10.67 3,727.58 3,633.44 5,516.86 163.91 5,964,653.06 1,700,822.18 0.48 5,516.86 MWD+1FR-AK-CAZ-SC(6) 8,817.05 88.57 10.74 3,729.36 3,635.22 5,609.33 181.40 5,964,745.66 1,700,838.91 0.74 5,609.33 MWD+IFR-AK-CAZ-SC(6) 8,912.30 87.84 9.84 3,732.34 3,638.20 5,703.00 198.40 5,964,839.46 1,700,855.17 1.22 5,703.00 MWD+IFR-AK-CAZ-SC(6) 8,960.10 87.74 9.71 3,734.19 3,640.05 5,750.08 206.51 5,964,886.59 1,700,862.90 0.36 5,750.08 MWD+1FR-AK-CAZ-SC(6) 4 1/2"x 6-3/4" 9,008.13 87.63 9.57 3,736.13 3,641.99 5,797.39 214.54 5,964,933.96 1,700,870.55 0.36 5,797.39 MWD+1FR-AK-CAZ-SC(6) 9,075.00 87.63 9.57 3,738.89 3,644.75 5,863.27 225.65 5,964,999.92 1,700,881.13 0.00 5,863.27 PROJECTED to TD 5/28/2015 10:00:57AM Page 5 COMPASS 5000.1 Build 65 • 0 0 To c Do N =4.iII d y a) Q N O ,i O CO O L > — E a 0 in 7,_ON aa, 6"— co o t0 c E a`, v av, 8 p_ .= R 43 f QN T . ti ;o 5 -52 ,! o LIv Q N O Ls O O o r6 N O N W }�� .O /i cv "O_ V /t. > co v1 c O O 4 o N a) O C O rN t v.. o0 U) � -0 fa E , Q V1 d = o_15 Jo 0 .a (1) cn a V# C) c z E o ° NC 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( C)\ ;ZNOR : EAN PARNLi L Anchorage Alaska 99501-3572 Main: 907 279 1433 '''r s 9C7 .776 713?2 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-143L3 ConocoPhillips Alaska, Inc. Permit No: 214-148 Surface Location: 280' FNL, 417' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 4969' FNL, 194' FEL, SEC. 11, Ti 1N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 214-145, API No. 50-029- 23528-00-00. Production should continue to be reported as a function of the original API number stated above. 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, die47 f--71)-(....,,4-L__ Cathy P. Foerster Chair DATED this 2=7 day of October, 2014. RECEIVED • STATE OF ALASKA 111 OCT 0 1 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL !�� . II j� 0 20 AAC 25.005 - Q/"--(ii Ue.P '- icy/ I� 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ Service- Winj 0 Single Zone [l/jzA 1 c.S eci if well Is proposed for: Drill 1:1 Lateral d Stratigraphic Test 0 Development-Gas 0 Service-Supply ❑ Multiple Zone 7 Coalbed Gas 0 Gas Hydrates 0 Redril Li Reentry 0 Exploratory 0 Service- WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 1D-143 L3 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9098'. ND: 3727' . Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 280'FNL 417'FEL,Sec.23 Twn 11N Rng 10 E,UM ' ADL 25650 and 25649 West Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4433'FNL 179'FEL,Sec.14 Twn 11N Rng 10E,UM ALK 468 and 467 12/1/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4969'FNL 194'FEL,Sec.11 Twn 11N Rng 10E,UM S710 _-2660-4 1 mile to KRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 98.7 feet ' 15.Distance to Nearest Well Open Surface:x-560672.6 y- 5959386.14 Zone-4 • GL Elevation above I 70.7 feet • to Same Pool: 100 ft 16.Deviated wells: Kickoff depth:y3109' 666 feet ' 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 9( .92.degrees Downhole: 1792 psi • Surface: 1389 psi ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD . TVD MD ND (including stage data) 40" 20" 94# K55 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2370' 28' 28' 2370' 2344' 1340 sx lead,245 sx tail DeepCRETE • 12.25" 9.625" 40# 1-80 Hydril 563 4309' 28' 28' 4309' 3664' 1155 sx Class'G' 6.75" 4.5" 11.6# L-80 IBTM 4939' 4159' 3614' 9098' 3727' Slotted liner(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 ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program ❑' Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 0 AAC 25..050 requirements0 21. Verbal Approval: Commission Representative: 4 Date "`/�1. ���"""111 22. I hereby certify that the foregoing is true and correct. David Lee @ 263-3741 . Contact david.I.Iee anconocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature AL I-.n../` Phone 265-6120 Date Ie4(t((¢ Commission Use Only Permit to Drill p API Number: _ Permit Approve ( 114 See cover letter for other Number: 1� -158' 50-09-1352s- O C� Date: +� " requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales: Er Other: w Pfes to 3 SUS psi Samples req'd: Yes NoRr Mud log req'd:Yes❑ No[r vL vt v L ear- ft 5 t- 74 r) 5`Z 0/�S r H2S measures: Yes No❑ Directional svy req'd:Yes No❑ Spacing exception req'd: Yes 0 No[✓j Inclination-only svy req'd:Yes 0 No IX APPROVED BY Approved by:a 'r , �y.0).('Z/V//r� COMMISSIONER THE COMMISSION Date:/(2 �7i�f "/ l "PM /O Z Submit Form and fI Form 10-401(Revised 10/2012) This permit Is valid for Z4 ohths from the date of appy ttachments in Duplicate V� /0/2-i //÷ � lP r �Fri )°� IAL RECEIVED STATE OF ALASKA ALlIkA OIL AND GAS CONSERVATION COMMON SEP 18 2014 PERMIT TO DRILL j'� 20 AAC 25.005 2Y� AVG 1 a.Type of Work: 'lb.Proposed Well Class: Development-Oil 0 Service- Winj 0 Single Zone © 1 c.Specify if well is% posed for: Drill -] Lateral Stratigraphic Test ❑ Development-Gas El Service Supply ❑ Multiple Zone I. Coalbed Gas ❑ as Hydrates ❑ Redril Li Reentry ❑ Exploratory ❑ Service WAG ❑ Service-Disp ❑ Geothermal / Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0. Single Well ❑ 11.Well Nam.-'and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180- 1D-143 L, `' 3.Address: 6.Proposed Depth: 12.Fiel ool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9090' • TVD: 3727' . Kupar River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): �/ Surface: 298'FNL 420'FEL,Sec.23 Twn 11 N Rng 10 E,UM • ADL 25650 and 25649 • 'fest Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: /13.Approximate Spud Date: 4414'FNL 181'FEL,Sec.14 Twn 11N Rng 10E,UM ALK 468 and 467 (/ 12/1/2014 Total Depth: 9.Acres in Property: / 14.Distance to Nearest Property: 4969'FNL 194'FEL,Sec.11 Twn 11N Rng 10E,UM 3 ,,ç /2&6O <1 mile to KRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 98.7 Afeet• 15.Distance to Nearest Well Open Surface:x-560670.04 y- 5959368.49 Zone-4 GL Elevation above I 70.7 i✓ feet_ to Same Pool: 100 ft r 16.Deviated wells: Kickoff depth:y 73bl 599 feet P44317.Maximum Anticipated Pressur in psig(see 20 AAC 25.035) Maximum Hole Angle: ¶ .92-degrees Downhole: 1792 psi• Surface: 1389 psi• 18.Casing Program: Specifications Top - Setting Dept!!- Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MDTVD ,�>/MD TVD (including stage data) 40" 20" 94# K55 Welded 80' 28' 28' ,(08' 108 200 cf of ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 2370' 28' 28' i%2370' 2344' 1340 sx lead,245 sx tail DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 4309' 28' 28' 4309' 3662' 1155 sx Class'G' 6.75" 4.5" 11.6# L-80 IBTM 4931' 4159' 3614/ 9090' 3727' Slotted liner(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completrOtedrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): \ ect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size c:)47 Cement Volume MD TVD Conductor/Structural ›�� Surface Intermediate \)>,/ t Production Liner Perforation Depth MD(ft): ` Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sk ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Div 'rt t ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: " ' Date 22. I hereby certify that the foregoing is true and corct. David Lee @ 263-3741 i Contact / Email david.l.lee c(�conocophillips.com Printed Name G.Alvord �� Title Alaska Drilling Manager r Signature Phone 265-6120 Date 6( (zp(4- Commission Use Only Permit to Drill / API Number: ,.., Permit Approval See cover letter for other Number: 141- i&i. /' 50- a9-.23502E-c1 6O Date: requirements. Conditions of approval: /If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 12( Other: /i Samples req'd: Yes❑ Nog Mud log req'd:Yes❑ No[/ / H2S measures: Yes[.f No❑ Directional svy req'd:Yes ENo❑ Spacing exception req'd: Yes EI No[" Inclination-only svy req'd:Yes❑ No[� APPROVED BY Approved by: RICOMMISSIIONNER THE COM/MIS/SION Date: J \t PL5( {�r'/Form 10-401(Revised 10/2012) This permit is vali o o f rrrllyll B ofa va AAC 225.005(g)) Attachments in Duplicate 4IV ConocoPhillips RECEIVED SEP 18 Alaska 2014 AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 David Lee Phone (907) 263-3741 July 11, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1D-1431,3 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a quad lateral horizontal well in the West Sak A2, A3, A4 and D sands. The expected spud date for 1D-143 is, December 1St, 2014. The West Sak in the 1D area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1D-143 well will be drilled down structure to the north with the A2 lateral being 6600' long, A3 lateral 3700' long, A4 lateral 7300'long and D lateral —4500'long. There is one major fault with a throw anticipated between 30— 35 feet down-to-the-north. There are no known H25 issues associated with the drilling of this well. The well is anticipated to see a reservoir pressures of—9.4 ppg in the D sand and —8.6 ppg in the A sands during the drilling of this well. The intermediate casing will set at 90 degrees in the A2 formation, the A2 lateral will be drilled and lined followed by the drilling and lining of the upper laterals in the following order, A3, A4, and D. 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. An FIT of 12.0ppg will also be performed after milling each window for the upper laterals 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 1D-143. 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. Sincerel • David Lee West Sak Drilling Engineer • ApplOn for Permit to Drill,Well 1D-143(D) Revision No.0 Saved: 12-Aug-14 Permit It - West Sak Well #1 D-143 L 3 , Application for Permit to Drill Document MaxWell P.1 jxirn ize 1hl�ll VQI4e Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 1D-143 PERMIT(D).doc Page 1 of 7 ORIGINAL Printed: 12-Aug-14 • Appl.n for Permit to Drill,Well 1 D-143(D) Revision No.0 Saved: 12-Aug-14 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Loads and CemCADE Summary 7 Attachment 4 Well Schematic 7 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1D-143 1_3 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 298' FNL 420' FEL Sec. 23 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 98.7'AMSL Northings 5,959,368.49 Eastings:560,670.04 Pad Elevation 70.7'AMSL Location at Top of Productive Interval 4414' FNL 181' FEL Sec. 14 Twn 11N Rng 10E UM (West Sak"D"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4318' Northings: 5,960,533.95 Eastings:560,898.52 Total Vertical Depth, RKB: 3664' Total Vertical Depth, SS: 3565' Location at Total Depth 4969' FNL 194' FEL Sec. 11 Twn 11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9090' Northings: 5,965,258.35 Eastings: 560,843.08 Total Vertical Depth, RKB: 3727' Total Vertical Depth, SS: 3628' 10-143 PERMIT(D).doc QRIGINALPage2of7 Printed: 12-Aug-14 • AppliOn for Permit to Drill,Well 1 D-143(D) Revision No.0 Saved: 12-Aug-14 and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: 1D-1431.3 Well Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 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 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1D-143. 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 maximum expected reservoir pressure in the West Sak D sand in the 1D area is 0.489 psi/ ft, or 9.4 ppg EMW. 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 1,389 psi, calculated thusly: MPSP = (3664 ft TVD)(0.489 - 0.11 psi/ft) = 1,389 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1D-143 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(t); 1D-143 will be completed with a 9-5/8" intermediate casing landed in the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation 1D-143 PERMIT(D).doc ORIGINAL Page 3 of 7 Printed: 12-Aug-14 • ApplOn for Permit to Drill,Well 1 D-143(D) Revision No.0 Saved: 12-Aug-14 Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. Upon sidetracking for each subsequent horizontal leg a formation integrity test will also be performed. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 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 2370 28/ 28 2370/ 2344 1340 sx 11.0ppg Deeperete Lead, 245 sx 12.0ppg DeepCRETE Tail Cement Top planned @ 2638' 9.625 12.25 40 L-80 Hydril 563 4309 28/ 28 4309/ 3662 MD/2565'TVD Cemented w/ 1155 sx 15.8 ppg Class`G' 4.5 6.75 11.6 L-80 IBTM 4931 4159/ 3614 9090/ 3727 slotted—no cement slotted 1D-143(D)Lateral milled out of 1D-143(A2)intermediate casing 6. Diverter System Information Requirements of 20 AAC 25.O05(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-143 surface hole. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 10-143 PERMIT(D).doc ORIGIN ALPage 4 of 7 Printed: 12-Aug-14 • Appin for Permit to Drill,Well 1 D-143(D) Revision No.0 Saved: 12-Aug-14 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Surface TD Value Density(ppg) 8.5 — 9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8-11.2 Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI FazePro OBM) Value 13 5/8"Csg Shoe to 9-5/8"Csg Point Density(ppg) 9.6 / Value Fann 35 6 RPM Density(ppg) 9.2 - 9.6 _ (lb/100 ft2) 4- 8 Fann 35 6 RPM HTHP Fluid Loss (lb/100 ft2) 12 - 16 (ml/30min) < 5 API Filtrate < 6 Drill Solids < 5% (cc/30 min)) pH 9.5 — 10.0 Oil water Ratio 70:30 Drill Solids <7 Electrical <400 Stability(mV) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 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. 1D-143 PERMIT(D).doc OR l...f pv I j I n ' L Page 5 of 7 Printed: 12-Aug-14 Applin for Permit to Drill,Well 1D-143(D) Revision No.0 Saved: 12-Aug-14 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); 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. LI L2 Note: Previous operations are covered under the 1D-143 {ickt, 1D-143`.6431 and 1D-143-(A4}Application for Permit to Drill. A 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 4309' MD/ 3662'TVD, right near the top of the D sand. 2. Mill 8-3/4"window and about 20'of new hole and perform FIT to 12.0 ppg EMW, recording results. POOH. 3. Pick up 6-3/4" bit, motor, MWD and magnet and perform clean out run and drill —200'of new hole. POOH. 4. Pick up 6-3/4"drilling assembly with MWD and LWD logging tools. RIH. j 3-- Ai 1 rl s1.v: I ?las Seo/ €. 5. Drill to TD of West Sak D Sand lateral at +/- 9090 MD / 3726 TVD, as per directional plan. 6. POOH, back reaming out of lateral to window. TIH to bottom &displace to solids-free oil based mud. Pump out of hole. 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 8. RIH and set Baker Seal Bore diverter 9. PU and run 4-1/2"slotted liner with Baker Oil Tools RAM Hangar system. 10. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH 11. Make up junction isolation / re-entry (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly (Torquemaster packer) and release from assembly. POOH. 12. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. 10-143 PERMIT(D).doc Page 6 of 7 ORIGINAL Printed: 12-Aug-14 Appian for Permit to Drill,Well 1D-143(D) Revision No.0 Saved: 12-Aug-14 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 1D-143 PERMIT(D).doc OR I G I N14 L Page7 of 7 Printed: 12-Aug-14 1D-143 rilling Hazards Summary 16" Open Hole / 10-3/8" 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 Anti-Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight,use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates,mud rheology, LCM Intermediate cement reaching Moderate Retard the first 60 bbls of cement to give us extra time surface casing shoe to get the well freeze protected prior to the cement setting up. 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 Intervals Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds, proper hole filling(use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions RI G INL Attachment 2-1D-143 Drilling Hazards Summary doc 8/12/20148:56:23 AM Anti-Collision Mate Follow real time surveys ver.sely, shut in nearby wells that we have collision concerns with. 1D-143 has collision concerns with 1D-140 which is a shut in producer that 1D-143 is replacing and iC-109 that will not be shut in as we have geological certainty that we are in a different zone than 1C-109, so we are confident we will not hit the well. Getting Liner to Bottom Moderate Maintain solids free oil based mud properties and lubricity while running liner lower completion,monitor torque and drag. Whipstock Retrieval Moderate Dedicated clean out runs prior to attempting to pull whipstock are planned to reduce the risk of fishing operations. ORIGINALAttachment 2-9D-943 Drilling Hazards Summary.doc 8/12/20148:56:23 AM 1 D-143 Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Nabors 9ES Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 1870' MD. Client:CPAI Revision Date: July 11,2014 Prepared by:Jenna Houston Location:Anchorage,AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -250 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11.00 ppg -1.91 ft3/100 lb sk email:jhouston2@sib.com 1.019 ft3/ft x 80 x 1.0 (0%excess) = 82 ft3 -1 < TOC at Surface 0.4206 ft3/ft x (1662-80) x 3.50 (250%excess) = 2329 ft3 0.4206 ft3/ft x (1870-1662) x 1.50 (50%excess) = 132 ft3 2329 ft3 + 132 ft3+82 ft3= 2543 ft3 2543 ft3/1.91 ft3/sk= 1332 sks(1340 sks) 1 Have additional ALC on location for Top Out stage,if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 1 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.4206 ft3/ft x (2370-1870) x 1.50 (50%excess) = 316 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 68 ft3 316 ft3+ 68 ft3 = 384 ft3 384 ft3/ 1.63 ft3/sk= 236 sks Round up to 245 sks BHST= 69°F, Estimated BHCT=78°F. (Based on 2.1°F/100 ft.from surface) < Base of Permafrost at PUMP SCHEDULE i 1,662'MD(1,650'TVD) Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW 100 7.0 75.0 10.7 10.7 MUDPUSH H 7.0 75.0 10.7 21.4 Pause 0.0 0.0 5.0 26.4 < Top of Tail at 11ppg DeepCRETE 7.0 452.6 64.7 it 1,870'MD Lead 91.1 Surface Tail 7.0 68.2 9.7 DeepCRETE Slurry 100.8 ,- Pause 0.0 0.0 5.0 105.8 Fresh Water 5.0 10.0 2.0 107.8 Pause 0.0 0.0 5.0 112.8 Mud 8.0 322.9 40.4 153.2 Mud 3.0 10.0 3.3 156.5 r < 13 3/8",68#casing 16"OH MUD REMOVAL Expected Mud Properties:10.0 ppg, Pv<20, Ty<20 :fix TD at 2,370 MD Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21, Ty=20-25 (2,344'TVD) Centralizers: As per CPAi program. Mark of Schlumberger ORIGINAL 1 D-143 Schiumberger CemCADE Preliminary Job Design 9 5/8" Intermediate (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig:Nabors 9ES Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: July 11,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time non-retarded slurry: -240 min. (pump time plus 120 Phone: (907)263-4207 min.). Minimum thickening time for retarded slurry is 480 min by COP request. Mobile: (907)223-8916 15.8 ppg Class G +adds- 1.16 ft3/sk email:jhouston2@slb.com 0.3132 ft3/ft x (5589'-2638') x 1.4(40%excess) = 1294 ft3 Shoe Volume: 0.4258 ft3/ft x 80'x 1.00 (no excess) = 35 ft3 Totals: 1294 ft3+35 ft3= 1329 ft3 1329 ft3/1.16 ft3/sk= 1146 sks(1155 sks) BHST= 102 °F, Estimated BHCT=80 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time ..... 13 3/8",45.5#casing Stage (bpm) Volume (min) Time (bbl) (min) at 2370'MD MUDPUSH II 5.0 50.0 10.0 10.0 Pause 0.0 0.0 5.0 15.0 Tail Slurry+retarder 5.0 60.0 12.0 P7.0 Tail Slurry 5.0 176.5 35.3 62.3 Pause 0.0 0.0 5.0 67.3 Fresh Water 5.0 10.0 2.0 69.3 Top of Tail at end of pumping Pause 0.0 0.0 5.0 74.3 < 2638'MD Mud 6.0 397.7 66.3 140.6 Mud 3.0 10.0 3.3 143.9 MUD REMOVAL 9 5/8",40# in 12 1/4"hole Recommended Mud Properties:9.6 ppg, Pv<20,Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties:10.5 ppg MudPUSH* Il, Pv 25 -30, Ty=30 -40 Centralizers: As per CPAi program TD at 5589'MD (3910 TVD) Mark of Schlumberger ORIGINAL • • I 0 n g,' •4:.,,',' g c. 2 MMS A.) V Q .... q O'-g° A o E tA 12 m"c c"1 A ¢o a a P. V. A rn a VO A`" rn o aco en qm w I tet' ' 'a 1 O N A a v o 1111 ^ a C9 WI En 4o lila lilt oo iv F t FI t0 ." C 7. Y a V _o U O — Cr', y ti I I a a 9 3 �h v 3 , .�I V. aS ' � � F U O 2 �' e a il an 1.4] � o �•, a3 a' y ii oa 1 L � 2. w f a II r m C d V i , :II 3 c Ill '8O �i VTJ ^ III C -. • V O C Ill . I O° M G a Ill Q i • ' , V o" o '� O n N III > m a F so a - rot I a s v ,v 3U 3 ��III, • a rn • x x a E U ^ f li ''' i :101# -8 .2 li i CA% ,-,2_„, Qn 0 o a � � 6A � a� a°' �NAT, m Y = `cU x o " 0 ' o 4 gq F.-,4 t r •*V/' T A i E a '' [s1 3 v, d r . a aD s_.aN " : ' t ^� s'iti"� .aw3AN . a H 34 /�ilt d G� tc .-.1 a o 'm y a'.aAF >� h .2 p, R7 itl ' LC ^ Q a ca 3 w F f: C a _> F 'Eh- a Q p A H Y al M q N Q .21,n d� TM.. on 1;1 F•• a3� ti 24 Y 7 U 4% ' .9 !- o i� i� masa'+ o 'Q A `oA `o. a p o m M y G F 2 G L =L al K ConocoPhillips 1D-143 Well Design Attachment rr,usn„» °.v:r (Quad Lateral) (IV P12)7/14/2014 Alaska ORIGINAL • 0 - v?- toIi ill DI 1D-143 L3wp 13 6.414 Plan Summary SURVEY PROGRAM pth From Depth To Survey/Plan Tool 28.00 1300.00 1D-143wp13 (Plan: 1D-143) GYD-GC-SS - --- (1500° 1300.00 2370.31 1D-143wp13 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC 112500 2370.31 4309.00 1D-143wp13 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC iI00w 4309.00 4577.03 1D-143L3wp13 (Plan: 1D-143L3) INC+TREND 4577.03 4600.00 1D-143L3wp13 (Plan: 1 D-143L3) INC+TREND1500 4600.00 6100.00 1D-143L3wp13 (Plan: 1D-143L3) MWD I 5000 4600.00 9098.02 1D-143L3wp13 (Plan: 1D-143L3) MWD+IFR-AK-CAZ-SC 2500 i%�ilik - = 0 CASING DETAILS \\,, -2500- 5000 TVD MD Name Size I " +_ -1500 3694.19 4577.03 9-5/8"x 12-1/4" 9-5/8 I I 1000(1 3726.70 9098.02 4-1/2"x 6-3/4" 4-1/2 -I2500 11 ° / 1011101 o° >.5- - -5 iYl�„ 4 0 a, i - _ _ 9'5, �x 2-1/4" - - - 2000 a' 9-5/8"x 12-1/4" 4-1/2"x 6-3/4' a , o - o y:o o ,,oo ° o I o o I ob D _ M -_--- ••'`��co6Na' m coon m nzs n , 0 I I i I I I I ` I f I I I I I f 0 o.• - 0 13-3/8"x 16" 5000 7500 0 850 1700 2550 3400 '250 5100 5950 Measured Depth Horizontal Departure 0 4309 c - ---- ---- ---_ -_- ._- 1D 1 330 0- 30 45.= I - 1-D-143 $ -�. 4500 4700 a_ - T I 300 60 4) 4 . 270 : sw - y` _ ' 5839 5300 m 30i 90 - sloo MINOR his , = � 240 120 0Iet. - 7100- 7400 - I I I l l I l l l I I I I 1 1 I I I + I I I I I I I 1 I I VL'' 90 593 - 7300 0 1000 2000 3000 4000 5000 6000 70001 8000 9000 210 °; • 150 180 - 8300 8500 SECTION DETAILS °°^^ w^^^ Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 4309.00 76.93 352.90 3664.26 1129.17 237.07 0.00 0.00 1129.17 KOP:13.56°/100'DLS,0°TF,for 16.5' 2 4325.50 79.17 352.90 3667.67 1145.19 235.07 13.56 0.00 1145.19 Hold for 30' 3 4355.50 79.17 352.90 3673.31 1174.43 231.43 0.00 0.00 1174.43 Start 4.89°/100'DLS,-0.53°TF,for 221.53' 4 4577.03 90.00 352.80 3694.19 1392.94 204.02 4.89 -0.53 1392.94 Hold for 30' 5 4607.03 90.00 352.80 3694.19 1422.70 200.26 0.00 0.00 1422.70 Start 3°/100'DLS,-4.26°TF,for 40.36' 6 4647.40 91.21 352.71 3693.76 1462.74 195.17 3.00 -4.26 1462.74 Hold for 976.63' 7 5624.03 91.21 352.71 3673.18 2431.26 71.27 0.00 0.00 2431.26 Start 3°/100'DLS,150.62°TF,for 160.96' 8 5784.99 87.00 355.08 3675.70 2591.24 54.16 3.00 150.62 2591.24 1D-143 D-Lat MW 02May14 CP1 S_fMdjust TF to 179.9°,for 111.89' 9 5896.88 83.64 355.09 3684.83 2702.33 44.60 3.00 179.90 2702.33 Hold for 147.26' 10 6044.14 83.64 355.09 3701.13 2848.15 32.06 0.00 0.00 2848.15 Start 3°/100'DLS,30.29°TF,for 237.34' 11 6281.48 89.80 358.67 3714.70 3084.59 19.19 3.00 30.29 3084.59 1D-143 D-Lat MW 29Jan14 CP2 N_fl6tart 2°/100'DLS,-0.52°TF,for 14.2' 12 6295.68 90.08 358.67 3714.71 3098.79 18.86 2.00 -0.52 3098.79 Hold for 1485.49' 13 7781.17 90.08 358.67 3712.54 4583.88 -15.69 0.00 0.00 4583.88 Start 2°/100'DLS,179.79°TF,for 35.2' 14 7816.38 89.38 358.67 3712.70 4619.07 -16.51 2.00 179.79 4619.07 1D-143 D-Lat MW 29Jan14 CP3 Adjust TF to 90.11°,for 941.26' 15 8757.64 89.38 17.50 3723.00 5546.74 115.24 2.00 90.11 5546.74 Hold for 340.38' 16 9098.02 89.38 17.50 3726.70 5871.36 217.57 0.00 0.00 5871.36 1D-143 D-Lat MW 29Jan14 CP4 TDMI 9098.02'MD,3726.7'TVD Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 TM Depth Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Magnetic Model Date: 30-Sep-14 System(SS)Reference: Mean Sea Level a Magnetic c DirDecliction: a True lEb- North /Y. 5959137.65 y To convert a Magnetic Direction to a True Direction,Add 19.29°East Ground Level/Mud Line: 70.70 East/ X: 1700704.56 Rig: Doyon 141 trror creating xuL parser for script. The nerameter is it-ismer-it 1 D-1 43L3wp1 2.1 Plan View 5700— 4-1/2"x 6-3/4" 4750— 8000 -143�34p r2 §800— 7000 rn X850— 6000 0 Z D 0 (900— 5000 9-5/8"x 12-1/4" If 950— 4000 0— A�'' 3000 I I 13-3/8"x16" I- _ I I -3800 -2850 -1900 -950 0 950 1900 2850 3800 West(-)/East(+) (950 usft/in) 0 0 1D-143L3wp12.1 Section View -1000-- 0- 1000-0—A . 0° 1000— 10000 7 0 0 C._ 9° o 2000— 2000 0 13-3/8"x16" U Q > 3(0 1D-143L3wp12.1 53000— ° o 1D-143L1wp12.1 I— coo o ° o 0 v o 0 0 . co 1 D-143L2wp12.1 4000- 9-5/8"x 12-1/4" 4-1/2"x 6-3/4" 1D-143wp12.1 5000— I I I I I 1 I i i i 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Vertical Section at 0.00°(1000 usft/in) I 403 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-143 Plan: 1D-143L3 Plan: 1 D-143L3wp13 a hfil-Comsion Plan Report - Map Coordinates $ 30 September,2014 • 0 Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:10-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 10 Pad,KRU Site Position: Northing: 5,959,421.20 usft Latitude: 70°18'0.267 N From: Map Easting: 1,701,118.42 usft Longitude: 149°30'30.085 W Position Uncertainty: 0.00 usft Slot Radius: 36" Grid Convergence: 0.46° Well Plan:1D-143 Well Position -1-NI-S 0.00 ash Northing: 5,959,137.65 usft Latitude: 70°17'57.510 N +EI-W 0.00 usft Easting: 1,700,704.56 usft Longitude: 149°30'42.218 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 70.70 usft Wellbore Plan:1D-143L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 11 11 (nT) BGGM2014 9/30/2014 19.29 80.92 57.583 Design 1D-143L3wp13 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,309.00 Vertical Section: Depth From(TVD) +NI-S +El-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 0.00 9/30/2014 6:22:28PM i.'+:ie 0 COMPASS 5000.1 Build 65 • • Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:10-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Survey Tool Program Date 9/30/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,300.00 1D-143wp13(Plan:1D-143) GYD-GC-SS Gyrodata gyro single shots 1,300.00 2,370.31 1D-143wp13(Plan:1D-143) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 2,370.31 4,309.00 1D-143wp13(Plan:1D-143) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,309.00 4,577.03 1D-143L3wp13(Plan:1D-143L3) INC+TREND Inclinometer+known azi trend 4,577.03 4,600.00 1D-143L3wp13(Plan:1D-143L3) INC+TREND Inclinometer+known azi trend 4,600.00 6,100.00 1D-143L3wp13(Plan:1 D-143L3) MWD MWD-Standard 4,600.00 9,098.02 1D-143L3wp13(Plan:1D-143L3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi ND TVD(Subsea) DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°A 00usft) (°) (usft) (usft) (usft) (usft) 4,309.00 76.93 352.90 3,664.26 3,565.56 3.01 14.48 5,960,268.58 1,700,932.54 7.08 2.08 KOP:13.56"I100'DLS,0°TF,for 16.5' 4,325.50 79.17 352.90 3,667.67 3,568.97 13.56 0.00 5,960,284.58 1,700,930.41 7.81 2.06 Hold for 30' 4,355.50 79.17 352.90 3,673.31 3,574.61 0.00 0.00 5,960,313.79 1,700,926.54 16.45 2.50 Start 4.691100'DLS,-0.53°TF,for 221.53' 4,400.00 81.34 352.88 3,680.84 3,582.14 4.89 -0.53 5,960,357.26 1,700,920.76 32.88 3.48 4,500.00 86.23 352.83 3,691.66 3,592.96 4.89 -0.53 5,960,455.76 1,700,907.61 72.04 10.25 4,577.03 90.00 352.80 3,694.19 3,595.49 4.89 -0.52 5,960,532.04 1,700,897.38 3,977,726,674.04 3,977,726,674.05 Hold for 30'-93/8".x 12-114" 4,600,00 90.00 352.80 3,694.19 3,595.49 0.00 -0.52 5,960,554.80 1,700,894.32 4,200,476,996.42 4,200,476,996.43 4,607.03 90.00 352.80 3,694.19 3,595.49 0.00 0.00 5,960,561.77 1,700,893.38 4,268,711,965.77 4,268,711,965.78 Start 31100'DLS,-4.26°TF,for 40.36' 4,647.40 91.21 352.71 3,693.76 3,595.06 3.00 -4.26 5,960,601.77 1,700,887.97 4,268,706,696.52 4,268,711,965.78 Hold for 976.63' 4,700.00 91.21 352.71 3,692.66 3,593.96 0.00 0.00 5,960,653.87 1,700,880.88 4,268,706,696.52 4,268,711,965.78 4,800.00 91.21 352.71 3,690.55 3,591.85 0.00 0.00 5,960,752.93 1,700,867.40 4,268,706,696.52 4,268,711,965.78 4,900.00 91.21 352.71 3,688.44 3,589.74 0.00 0.00 5,960,851.98 1,700,853.92 4,268,706,696.52 4,268,711,965.78 9!302014 6:22:28PM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 t 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28©98.70usft(Doyon 141) Well: Plan:10-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi TVD TVD(Subsea) DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 5,000.00 91.21 352.71 3,686.33 3,587.63 0.00 0.00 5,960,951.04 1,700,840.44 4,268,706,696.52 4,268,711,965.78 5,100.00 91.21 352.71 3,684.23 3,585.53 0.00 0.00 5,961,050.09 1,700,826.95 4,268,706,696.52 4,268,711,965.78 5,200.00 91.21 352.71 3,682.12 3,583.42 0.00 0.00 5,961,149.15 1,700,813.47 4,268,706,696.52 4,268,711,965.78 5,300.00 91.21 352.71 3,680.01 3,581.31 0.00 0.00 5,961,248.20 1,700,799.99 4,268,706,696.52 4,268,711,965.78 5,400.00 91.21 352.71 3,677.90 3,579.20 0.00 0.00 5,961,347.26 1,700,786.51 4,268,706,696.52 4,268,711,965.78 5,500.00 91.21 352.71 3,675,80 3,577.10 0.00 0.00 5,961,446.31 1,700,773.03 4,268,706,696.52 4,268,711,965.78 5,600.00 91.21 352.71 3,673.69 3,574.99 0.00 0.00 5,961,545.37 1,700,759.55 4,268,706,696.52 4,268,711,965.78 5,624.03 91.21 352.71 3,673.18 3,574.48 0.00 0.00 5,961,569.17 1,700,756.31 4,268,706,696.52 4,268,711,965.78 Start 3°/100'DLS,150.62°TF,for 160.96' 5,700.00 89.22 353.83 3,672.90 3,574.20 3.00 150.62 5,961,644.53 1,700,746.81 4,268,024,963.32 4,288,711,965.78 5,784.99 87.00 355.08 3,675.70 3,577.00 3.00 150.63 5,961,728.99 1,700,737.92 4,265,332,609.54 4,268,711,965.78 Adjust TF to 179.9°,for 111.89' 5,800.00 86.55 355.08 3,676.54 3,577.84 3.00 179.90 5,961,743.91 1,700,736.51 4,265,330,161.56 4,268,711,965.78 5,896.88 83.64 355.09 3,684.83 3,586.13 3.00 179.90 5,961,839.99 1,700,727.47 4,265,314,272.98 4,268,711,965.78 Hold for 147.26' 5,900.00 83.64 355.09 3,685.17 3,586.47 0.00 0.00 5,961,843.08 1,700,727.18 4,265,314,272.98 4,268,711,965.78 6,000.00 83.64 355.09 3,696.24 3,597.54 0.00 0.00 5,961,942.02 1,700,717.88 4,265,314,272.98 4,268,711,965.78 6,044.14 83.64 355.09 3,701.13 3,602.43 0.00 0.00 5,961,985.69 1,700,713.77 4,265,314,272.98 4,268,711,965.78 Start 3°/100'DLS,30.29°TF,for 237.34' 6,100.00 85.09 355.93 3,706.61 3,607.91 3.00 30.29 5,962,041.07 1,700,708.97 4,262,326,342.54 4,268,711,965.78 6,200.00 87.69 357.44 3,712.91 3,614.21 3.00 30.20 5,962,140.63 1,700,702.41 4,254,696,565.62 4,268,711,965.78 6,281.48 89.80 358.67 3,714.70 3,616.00 3.00 30.11 5,962,222.00 1,700,699.00 4,246,328,986.57 4,268,711,965.78 Start 2°1100'DLS,-0.52°TF,for 14.2' 6,295.68 90.08 358.67 3,714.71 3,616.01 2.00 -0.52 5,962,236.19 1,700,698.56 4,246,348,657.80 4,268,711,965.78 Hold for 1485.49' 6,300.00 90.08 358.67 3,714.71 3,616.01 0.00 0.00 5,962,240.51 1,700,698.42 4,246,348,657.80 4,268,711,965.78 6,400.00 90.08 358.67 3,714.56 3,615.86 0.00 0.00 5,962,340.46 1,700,695.29 4,246,348,657.80 4,268,711,965.78 6,500.00 90.08 358.67 3,714.41 3,615.71 0.00 0.00 5,962,440.40 1,700,692.17 4,246,348,657.80 4,268,711,965.78 9/302014 6:22:28PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kupt Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70ustt(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28(t 98.70ustt(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi TVD TVD(Subsea) DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) ,,,. (°) (usft) (usft) (°1100usft) (°) (usft) %%:, (usft) (usft) (usft) 6,600.00 90.08 358.67 3,714.27 3,615.57 0.00 0.00 5,962,540.34 1,700,689.04 4,246,348,657.80 4,268,711,965.78 6,700.00 90.08 358.67 3,714.12 3,615.42 0.00 0.00 5,962,640.28 1,700,685.91 4,246,348,657.80 4,268,711,965.78 6,800.00 90.08 358.67 3,713.97 3,615.27 0.00 0.00 5,962,740.22 1,700,682.78 4,246,348,657.80 4,268,711,965.78 6,900.00 90.08 358.67 3,713.83 3,615.13 0.00 0.00 5,962,840.16 1,700,679.66 4,246,348,657.80 4,268,711,965.78 7,000.00 90.08 358.67 3,713.68 3,614.98 0.00 0.00 5,962,940.10 1,700,676.53 4,246,348,657.80 4,268,711,965.78 7,100.00 90.08 358.67 3,713.53 3,614.83 0.00 0.00 5,963,040.05 1,700,673.40 4,246,348,657.80 4,268,711,965.78 7,200.00 90.08 358.67 3,713.39 3,614.69 0.00 0.00 5,963,139.99 1,700,670.28 4,246,348,657.80 4,268,711,965.78 7,300.00 90.08 358.67 3,713.24 3,614.54 0.00 0.00 5,963,239.93 1,700,667.15 4,246,348,657.80 4,268,711,965.78 7,400.00 90.08 358.67 3,713.09 3,614.39 0.00 0.00 5,963,339.87 1,700,664.02 4,246,348,657.80 4,268,711,965.78 7,500.00 90.08 358.67 3,712.95 3,614.25 0.00 0.00 5,963,439.81 1,700,660.89 4,246,348,657.80 4,268,711,965.78 7,600.00 90.08 358.67 3,712.80 3,614.10 0.00 0.00 5,963,539.75 1,700,657.77 4,246,348,657.80 4,268,711,965.78 7,700.00 90.08 358.67 3,712.65 3,613.95 0.00 0.00 5,963,639.69 1,700,654.64 4,246,348,657.80 4,268,711,965.78 7,781.17 90.08 358.67 3,712.54 3,613.84 0.00 0.00 5,963,720.82 1,700,652.10 4,246,348,657.80 4,268,711,965.78 Start 21100'DLS,179.79°TF,for 35.2' 7,800.00 89.71 358.67 3,712.57 3,613.87 2.00 179.79 5,963,739.63 1,700,651.51 4,246,338,138.45 4,268,711,965.78 7,816.38 89.38 358.67 3,712.70 3,614.00 2.00 179.79 5,963,756.00 1,700,651.00 4,246,328,986.57 4,268,711,965.78 Adjust TF to 90.11°,for 941.26' 7,900.00 89.38 0.34 3,713.61 3,614.91 2.00 90.11 5,963,839.60 1,700,649.61 4,231,777,192.17 4,268,711,965.78 8,000.00 89.37 2.34 3,714.70 3,616.00 2.00 90.09 5,963,939.56 1,700,651.15 4,209,642,820.04 4,268,711,965.78 8,100.00 89.37 4.34 3,715.79 3,617.09 2.00 90.07 5,964,039.42 1,700,656.18 4,182,379,019.65 4,268,711,965.78 8,200.00 89.37 6.34 3,716.89 3,618.19 2.00 90.05 5,964,139.03 1,700,664.69 4,150,019,007.21 4,268,711,965.78 8,300.00 89.37 8.34 3,717.99 3,619.29 2.00 90.03 5,964,238.29 1,700,676.67 4,112,602,214.77 4,268,711,965.78 8,400.00 89.37 10.34 3,719.09 3,620.39 2.00 90.01 5,964,337.07 1,700,692.11 4,070,174,242.07 4,268,711,965.78 8,500.00 89.37 12.34 3,720.19 3,621.49 2.00 89.98 5,964,435.25 1,700,710.99 4,022,786,800.88 4,268,711,965.78 8,600.00 89.37 14.34 3,721.28 3,622.58 2.00 89.96 5,964,532.72 1,700,733.28 3,970,497,651.76 4,268,711,965.78 8,700.00 89.38 16.34 3,722.37 3,623.67 2.00 89.94 5,964,629.34 1,700,758.96 3,913,370,533.39 4,268,711,965.78 9/30/2014 6:22:28PM Page 5 COMPASS 50001 Build 65 ! • Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan.1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1 D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi TVD TVD(Subsea) DLeg TFace Northing Easting Let.Error Vert.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) (usft) 8,757.64 89.38 17.50 3,723.00 3,624.30 2.00 89.92 5,964,684.60 1,700,775.29 3,878,274,381 00 4,268,711,965.78 Hold for 340.38' 8,800.00 89.38 17.50 3,723.46 3,624.76 0.00 -140.59 5,964,725.10 1,700,787.70 3,878,274,381.00 4,268,711,965.78 8,900.00 89.38 17.50 3,724.55 3,625.85 0.00 0.00 5,964,820.70 1,700,816.99 3,878,274,381.00 4,268,711,965.78 9,000.00 89.38 17.50 3,725.63 3,626.93 0.00 0.00 5,964,916.30 1,700,846.29 3,878,274,381.00 4,268,711,965.78 9,098.02 89.38 17.50 3,726.70 3,628.00 0.00 0.00 5,965,010.00 1,700,875.00 3,878,274,381.00 4,268,711,965.78 TO:9098.02'MD,3726.7'TVD 9/30/2014 6:22:28PM Page 6 COMPASS 5000.1 Build 65 0 0 Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28(fp 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28(fp 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1D-143 D-Lat MW 29Jar 0.00 0.00 3,726.70 5,871.36 217.57 5,965,010.00 1,700,875.00 70°18'55.257 N 149°30'35.870 W -plan hits target center -Point 10-143 0-Lat MW 29Jar 0.00 0.00 3,712.70 4,619.07 -16.51 5,963,756.00 1,700551.00 70°18'42.940 N 149°30'42.699 W -plan hits target center -Point Mr11111111111111161=.11 MI MIIIIIIIIIILa6OMINIIMMMMIII.M.INI OM 1D-143 D-Lat MW 02Ma 0.00 0.00 3,675.70 2,591.24 54.16 5561,728.99 1,700,737.92 70°18'22.996 N 149°30'40.638 W -plan hits target center -Point Mill1111.11=111.111=11=1111111 MN MIPIIIIIIMIIMIE. EMI 10-143 D-Lat MW 29Jar 0.00 0.00 3,714.70 3,084.59 19.19 5,962,222.00 1,700,699.00 70°18'27.848 N 149°30'41.658 W -plan hits target center -Point 9/30/2014 6:22:26PM Page 7 COMPASS 5000.1 Build 65 0 0 Schlumberger Plan Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan.70.7+26 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+26 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp13 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 1"1 1"1 9,098.02 3,726.70 4-1/2"x 6-3/4" 4-1/2 6-3/4 4,577.03 3,694.19 9-5/8"x 12-1/4" 9-5/8 12-1/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/-W (usft) (usft) (usft) (usft) Comment e,. /36/. r T,P1U 4,309.00 3,664.26 1,129.17 237.07 KOP:13.56'1100'DLS,0°TF,for 16.5' 4,325.50 3,667.67 1,145.19 235.07 Hold for 30' 4,355.50 3,673.31 1,174.43 231.43 Start 4.89°/100'DLS,-0.53°TF,for 221.53' 4,577.03 3,694.19 1,392.94 204.02 Hold for 30' 4,607.03 3,694.19 1,422.70 200.26 Start 3°/100'DLS,-4.26°TF,for40.36' 4,647.40 3,693.76 1,462.74 195.17 Hold for 976.63' 5,624.03 3,673.18 2,431.26 71.27 Start 3°/100'DLS,150.62°TF,for 160.96' 5,784.99 3,675.70 2,591.24 54.16 Adjust TF to 179.9°,for 111.89' 5,896.88 3,684.83 2,702.33 44.60 Hold for 147.26' 6,044.14 3,701.13 2,848.15 32.06 Start 3°/100'DLS,30.29°TF,for 237.34' 6,281.48 3,714.70 3,084.59 19.19 Start 2°/100'DLS,-0.52°TF,for 14.2' 6,295.68 3,714.71 3,098.79 18.86 Hold for 1485.49' 7,781.17 3,712.54 4,583.88 -15.69 Start 2°/100'DLS,179.79°TF,for 35.2' 7,816.38 3,712.70 4,619.07 -16.51 Adjust TF to 90.11°,for 941.26' 8,757,64 3,723.00 5,546.74 115.24 Hold for 340.38' 9,098.02 3,726.70 5,871.36 217.57 TD:9098.02'MD,3726.7'TVD Checked By. Approved By Date. 9/30/2014 6:22:28PM Page 8 COMPASS 5000.1 Build 65 I • -16,0W - /o,(/ly ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-143 Plan: 1D-143L3 1 D-143L3wp13 Clearance Summary Report 30 September,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) MIN . s ked Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L3-1D-143L3wp13 Well Coordinates: 5,959,137.65 N,1,700,704.56 E(70°17'57.51"N,149°30'42.22"W) Datum Height: Plan:70.7+28 98.70usft(Doyon 141) Scan Range: 4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft. Clearance Factor cutoff is Unlimited. 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C O m N- (0 0 ) (V ,- o 47, d (U!/o9 Z)Jopoed uo!leaedag Q U ORIGINAL S • Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 22, 2014 10:34 AM To: Loepp,Victoria T (DOA) Subject: RE: KRU 1D-143L1(PTD 214-146); KRU 1D-143L3(PTD 214-148)Anti-collision analysis Follow Up Flag: Follow up Flag Status: Completed Morning Victoria,the wells that we failed major risk were: 1C-109 (laterals in B and D)—TCR has been completed, will mitigate by: When we drill the lowest lateral (1D-143), and L2 lateral we will be using periscope so leaving risk of leaving zone is minimal, and since 1C-109 has laterals in the B and D sands, if we don't leave zone we will not hit the well. 10-140 (laterals in B and D) )—TCR has been completed,will mitigate by: When we drill the lowest lateral (10-143), L1 and L2 laterals we will be using periscope so leaving risk of leaving zone is minimal,and since 1D-140 has laterals in the B and D sands, if we don't leave zone we will not hit the well. For the L3 lateral,when drilled we will closely monitor for magnetic interference, and if interference is picked up we will drill away from the well. 1D-140 is currently shut in and suspended, so if we did hit it while drilling there is no environmental or safety risk. 1D-143 (Colliding laterals with themselves)—All laterals will be drilled using periscope so risk of leaving zone is minimal eliminating the collision risk. 1D-145 (planned well)—1D-145 is a planned well to be drilled after 10-143, 1D-143 will be drilled using periscope and 1D-145 lateral is going to be in the B sand, so risk of crossing planned line is minimal. If we did cross the planned line 1D-145 would just have to be re planned. If you have further questions or any concerns please let me know. David From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 21, 2014 4:33 PM To: Lee, David L Subject: [EXTERNAL]KRU 10-143L1(PTD 214-146); KRU 10-143L3(PTD 214-148)Anti-collision analysis David, 1. Anti-collision analysis 1D-143L1: 10-01, 10-101, 10-108. 10-107 fail major risk:What steps will be taken with these wells to mitigate risk of collision during drilling 1D-143L1? Did I miss the TCRs or explanation? 2. Anti-collision analysis 1D-143L3: 1C-127, 1D-01, 1D-09, 10-101, 10-106, 1D-107, 10-118, 10-14 fail major risk: What steps will be taken with these wells to mitigate risk of collision during drilling 1D-143L13? Did I miss the TCRs or explanation? Thanx, Victoria Victoria Loepp 1 • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-143 Plan: 1D-143L3 1 D-143L3wp13 Clearance Summary Anticollision Report 23 October,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:10-143-Plan:1D-143L3-10-143L3wp13 Well Coordinates:5,959,137.65 N,1,700,704.56 E(70°17'57.51"N,149°30'42.22"W) Datum Height: Plan:70.7+28 @ 98.70usft(Doyon 141) Scan Range:4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:65 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L3wp13 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:10-143-Plan:1D-143L3-1D-143L3wp13 Scan Range: 4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 1C Pad 1C-127-1C-127-1C-127 8,818.03 1,077.48 8,818.03 844.19 5,800.00 4_619 Centre Distance Pass-Major Risk 1C-127-1C-127-1C-127 8,808.12 1,077.64 8,808.12 843.95 5,825.00 4.611 Clearance Factor Pass-Major Risk Kuparuk 1D Pad 1D-01-1D-01-1D-01 4,737.90 790.18 4,737.90 676.21 3,725.00 6.934 Centre Distance Pass-Major Risk 10-01-10-01-10-01 4,889.00 799.01 4,889.00 672.32 3,950.00 6.307 Clearance Factor Pass-Major Risk 16-04-1D-04-10-04 4,313.26 732.20 4,313.26 622.89 4,225.00 6.699 Clearance Factor Pass-Major Risk 1604-1D-04A-1D-04A 4,313.26 732.20 4,313.26 622.89 4,225.00 6.699 Clearance Factor Pass-Major Risk 10-04-1D-04AL1- 1D-04AL1 4,313.26 732.20 4,313.26 622.89 4,225.00 6.699 Clearance Factor Pass-Major Risk 1604-1D-04AL1-01-1D-04AL1-01 4,313.26 732.20 4,313.26 622.89 4,225.00 6.699 Clearance Factor Pass-Major Risk 1604-1D-04AL1-02.1D-04AL1-02 4,313.26 732.20 4,313.26 622.89 4,225.00 6.699 Clearance Factor Pass-Major Risk 10-09-1609-1609 4,309.00 599.66 4,309.00 514.49 4,200.00 7.041 Clearance Factor Pass-Major Risk 16101-16101-16101 7,011.53 918.43 7,011.53 704.01 5,450.00 4.283 Centre Distance Pass-Major Risk 10-101-16101-16101 7,032.70 918.83 7,032.70 702.99 5,500.00 4.257 Clearance Factor Pass-Major Risk 16106-16106-16106 5,309.92 537.48 5,309.92 418.31 4,325.00 4.510 Centre Distance Pass-Major Risk 16106-16106-16106 5,318.01 537.91 5,318.01 417.84 4,350.00 4.480 Clearance Factor Pass-Major Risk 10.107-16107-16107 6,767.51 687.16 6,767.51 490.09 5,450.00 3.487 Centre Distance Pass-Major Risk 16107-16107-16107 6,872.85 690.81 6,872.85 486.45 5,575.00 3.380 Clearance Factor Pass-Major Risk 16118-16118-10-118 4,515.82 428.22 4,515.82 326.19 3,925.00 4.197 Centre Distance Pass-Major Risk 16118-16118-16118 4,525.28 428.47 4,525.28 326.00 3,950.00 4.181 Clearance Factor Pass-Major Risk 10-14-1614-1614 4,324.45 770.26 4,324.45 684.23 3,650.00 8.954 Clearance Factor Pass-Major Risk 10.140-10.140-10.140 willm. l. 0.617 Centre Distance FAIL-Major Risk 16140-10-140-16140 I ism • 148.50 8,20 I -93.4 It 7,975.00 11110.814 Clearance Factor FAIL-Major Risk 16140-1D-140L1-1D-140 Lt @ AIM IIII. 91.26 5,981. -96.14 • 5,700.00 mu0.487 Centre Distance FAIL-Major Risk 16140-1D-140L1-16140 L1 •, 104.58 7,901. 1 -145.0 III 0.418 Clearance Factor FAIL-Major Risk 16140-1 D-140P81-1D-140PB1 - r, 159.08 5,59011 p -2.4 •, 5,325.00 M 0.985 Centre Distance FAIL-Ili ji 16140-1D-140P81-1D-140PB1 - •': 169.51 6,041.74 -24.95 " 5,775.00 - 0.872 Clearance Factor FAIL- Plan:16143-Plan:16143-16143wp13 - III 0.30 4,324.99 -1.29 4,325.00 soL0.190 Clearance Factor FAIL- 23 October,2014- 15:25 COMPASS • i ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1D-143L3wp13 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L3-1D-143L3wp13 Scan Range:4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:1D-143-Plan:1D-143L1-1D-143L1wp13 4,3244 Illllll r'0.30 4,324.99 -1.29 4,325.00 0.190 Clearance Factor FAIL-Major Risk Plan:1D-143-Plan:1D-143L2-1D-143L2wp13 4,324.4 lir 0.30 4,3244 6 -1.29 4,325.00 0.190 Centre Distance FAIL-Major Risk Plan:1D-143-Plan:1D-143L2-1D-143L2wp13 8,670.56 Ir 122.01 8,670$ IIll_ -132.38 8,675.00 0.480 Clearance Factor FAIL-Major Risk Plan:10-145-Plan:1D-145-1 D-145wp06 5,929.88 57.05 5,929$ MD-20.10 6,300.00 0.739 Centre Distance FAIL-Major Risk Plan:1D-145-Plan:1D-145-1D-145wp06 8,676.08 65.06 8,6764 mum— -36.56 9,050.00 0.640 Clearance Factor FAIL-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 1,300.00 GYD-GC-SS 1,300.00 2,370.31 MWD+IFR-AK-CAZ-SC 2,370.31 4,309.00 MWD+IFR-AK-CAZ-SC 4,309.00 4,577.03 1D-143L3wp13 BLIND 4,577.03 4,600.00 1D-143L3wp13 BLIND 4,600.00 6,100.00 1D-143L3wp13 MWD 4,600.00 9,098.02 1D-143L3wp13 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 23 October,2014- 15:25 Page 3 of 5 COMPASS II • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L3wp13 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L3-1D-143L3wp13 Scan Range:4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft( usft Kuparuk 1C Pad 1C-127-IC-127-1C-127 9,071.99 i- 1,106.61 gip,.9,071.93 159,890,418.89 5,350.00 0.000 Clearance Factor FAIL-Major Risk 1C-127-1C-127-1C-127 8,818.09 .. 1,077.48 8,818.03 008,658,242.44 5,800.00 0.000 Centre Distance FAIL-Major Risk Kuparuk 1D Pad 1D-01-1D-01-1D-01 4,737.90 IL, 789.14 i 9,2,868,047.83 Ilaila 9110 Centre Distance 4. -,, /1.r " -_ 1D-01-1D-01-1D-01 5,066.14. 1.13 11. 01276,010.61 MEM MEI Clearance Facto 1D-04-1D-04-1D-04 4,313.26 73220 ` 4,313.26 622.44 4,225.00 6.671 Clearance Factor Pass-Major Risk 1D-04-1D-04A-1D-04A 4,313.26 732.20 4,313.26 622.44 4,225.00 6.671 Clearance Factor Pass-Major Risk 1D-04-1 D-04AL1- 1 D-04AL1 4,313.26 73 20 4,313.26 622.44 4,225.00 6.671 Clearance Factor Pass-Major Risk 1D-04-1D-04AL1-01-1D-04AL1-01 4,313.26 32.20 4,313.26 622.44 4,225.00 6.671 Clearance Factor Pass-Major Risk 1D-04-1 D-04AL1-02-1 D-04AL1-02 4,313.26 732.20 4,313.26 622.44 4,225.00 6.671 Clearance Factor Pass-Major Risk 1D-09-1D-09.1D-09 4,309.00 599.66 4,309.00 514.49 4,200.00 7.041 Centre Distance Pass-Major Risk 1D-09-1D-09-1D-09 ME= MEI=. 4,546.55 200,071,104.9 =MEM 0.000 Clearance Facto ajor Risk 1D-101-1D-101-1D-101 MIMS 11111ME 6,431.84 982,421,252.3( =111= 0.000 Clearance Factor ' 'major Risk 1D-101-1D-101-1D-101 ® IIIIMME, ", 7,011.53 956,044,778.6 milms 0.000 Centre Distance Major Risk 10-106-10-106-10-106 IIIIIENE it 591m ..,309.92 013,220,939.33 4,325.00 0.000 Centre Distance FAIL-Major Risk 1D-106-1D-106-10-106 ® It.. 541.3w iligif,334.03 013,275,503.71 4,400.00 0.000 Clearance Factor FAIL-Major Risk 1D-107-10-107-1D-107 ® •:'. 849.V 111.1710.00 013,274,591.18 4,275.00 0.000 Clearance Factor FAIL-Major Risk 10-107-10-107-1D-107 Et: 687.16, =IMO 958,017,596.50 5,450.00 0.000 Centre Distance FAIL-Major Risk 1D-118-1D-118-1D-118 gr- 428.2E MEI& 107,345,576.65 3,925.00 0.000 Centre Distance FAIL-Major Risk 1D-118-1D-118-1D-118 ® ®:: 50se 913,261,276.52 4,225.00 0.000 Clearance Factor FAIL-Major Risk 10-14-10-14-10-14 4,324.45 770.26 4.324.45 682.61 3.650.00 8.788 Centre Distance Pass-Major Risk 10-14-1D-14-10-14 4,618.91' 013,276,098.49 4,026.00 „admikplia Clearance Factor FAH.-Major Risk 1D-140-1D-140-1D-140 8,087.08 145.94 8,087.08 145.37 7,850.00 254.292 Clearance Factor Pass Minor 1/10 10-140-1D-140L1-10-140 L1 5,964.73 91.26 5,964.73 90.79 5,700.00 194.266 Clearance Factor Pass-Minor 1/10 10-140-1D-140PB1-1D-140PB1 5,590.96 159.08 5,590.96 158.51 5,325.00 277.190 Clearance Factor Pass-Minor 1/10 Plan:1D-143-Plan:1D-143-1D-143wp13 ® ® IIIIMIP -0.9 E 4,3220 Clearance Factor'_ FAIL-Minor 1120, Plan:1D-143-Plan:1D-143L1-1 D-143L1wp1 �1a-0.94 14,32 r 0.240 Clearance Factor Fel-.MIn •1 30 September,2014- 18:23 Page 2 of 5 COMPASS :'-..-r':'''' UP ERSE D • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L3wp13 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L3-1D-143L3wp13 Scan Range: 4,309.00 to 9,098.02 usft.Measured Depth. Scan Radius is 1,107.00 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:10-143-Plan:1D-143L2-1 D-143L2wp 13 111 11111 Plan:1D-145-Plan:1 D-145-1 D-145wp06 5,929.88 57.05 5,929.88 56.40 6,340.00 88.495 Clearance Factor Pass-Minor 1/10 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 1,300.00 GYD-GC-SS 1,300.00 2,370.31 MWD+IFR-AK-CAZ-SC 2,370.31 4,309.00 M WD+I FR-AK-CAZ-SC 4,309.00 4,577.03 1D-143L3wp13 INC+TREND 4,577.03 4,600.00 1D-143L3wp13 INC+TREND 4,600.00 6,100.00 1D-143L3wp13 MWD 4,600.00 9,098.02 1D-143L3wp13 MWD+IFR-AK-CAZ-SC • Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 30 September,2014- 18:23 Page 3 of 5 COMPASS S S w .r, Sec Inc Azi TVD +N/-S +E/-W Dleg TFace Target U 4JJU5 1 430 76.93 352.90 3664.26 1129.17 237.07 0.00 0.00 / 1 D-143L3wp13 2 4325.50 79.17 352.90 3667.67 1145.19 3 4355.50 79.17 352.90 3673.31 1174.43 235.07 231.43 13.56 0.00 1145.19 0.00 0.00 1174.43 4309 4500 4309.00 To 9098.02 4 4577.03 90.00 352.80 3694.19 1392.94 200.26 4.89 -0.53 1392.94 4500 4700 5 4607.03 90.00 352.80 3694.19 1422.70 200.26 0.00 0.00 1422.70 6 4647.40 91.21 352.71 3693.76 1462.74 195.17 3.00 -4.26 1462.74 ' 5624.03 91.21 352.71 3673.18 2431.26 71.27 0.00 0.00 2431.26 4700 4900 5784.99 87.00 355.08 3675.70 2591.24 54.16 3.00 150.62 2591.24 1D-143 D-Lat MW 02May14 CP1 Silt 18:20,September 30 2014 5896.88 83.64 355.09 3684.83 2702.33 44.60 3.00 179.90 2702.33 4900 5000 6044.14 83.64 355.09 3701.13 2848.15 32.06 0.00 0.00 2848.15 6281.48 89.80 358.67 3714.70 3084.59 19.19 3.00 30.29 3084.59 1 D-143 0-Lat MW 29Jan14 CP2 N_Ot 5000 5200 SURVEY PROGRAM 6295.68 90.08 358.67 3714.71 3098.79 18.86 2.00 -0.52 3098.79 )ep1F Fram Depth To surVeymbn Tool 7781.17 90.08 358.67 3712.54 4583.88 -15.69 0.00 0.00 4583.88 _ 28.00 1300.00 1D-143wp13(3lan)10143) GYI,GC-SS 7816.38 89.38 358.67 3712.70 4619.07 -16.51 2.00 179.79 4619.07 1D-143 D-Lat MW 29Jan14 CP3 5200 5400 1300.00 2370.31 11,143wp13(Plan)11-143) MWD.IFn-40-C4Z-SC 8757.64 89.38 17.50 3723.00 5546.74 115.24 2.00 90.11 5546.74 3370.31 4309.03 11,.143wp13(Plan)1)443) MWD0m-4K-CAZ-SC 9098.02 89.38 17.50 3726.70 5871.36 217.57 0.00 0.00 5871.36 1D-143 D-Lat MW 29Jan14 CP4 TD_D6 5400 5600 4507.03 460000 10-193139p13(Plan)10-14319E.TRElC 4577.03 460000 16143L1vp13(Plan:10-1431/SWO E,D 4600.00 6100.00 10.143L3wp13(Plan)11-143 VD 4600.00 909803 1D�143L3wp13(Plan)1D-143E6,YD.Im-AK-CAZ-SC 5600 5800 CASING DETAILS 5800 5900 TVD MD Name Size 5900 """ "" 6100 3694.19 4577.03 9-5/8"4 12-1/4" 9-5/8 3726.70 9098.02 4-1/2"x 6-3/4" 4-1/2 6100 6200 6200 6400 6400 6500 0/360 6500 6700 6700 6800 225 6800 7100 -30/330 210 30 7100 7400 195 7400 7700 180 7700 7900 165 7900 8200 :. 00 8200 8500 13 8500 8800 -60/300 60 8800 9098 90 75 60 II) -90/270 ..0.. Y 90 LUE 1 7 _ ) ..,,..,,-- 7 r, 54 e2, ��,.;, za -p:r i•:� ...,".,:i;':4 f; *1 ' - - .D-145 t 11 -120/240 113-1, p13 =Y7557 120 +06 43L1 wp 1 - - 1 :;:':-''1:1,-,t -150/210 210 P4:. 150 _6 143wp13 '46 -180/180 940 4- 11 + 1 - '0 -2 0303'11-,01012-103V1 0 4 10130 10,13330333 22 -d- 11773011 V* 41 1 306,,20001 V0 4 -X- 4 4. 11 192 $ 14 $ ID -i- 12 120 $ 10 9 ID $ 41, $ , $ 4 9 1 9 3 3P131 V3 $ 14 $ 9 4 i- 1 9 4 4€ 322 $ , V4 -$ 4 $ 4 9 4 4 $ 3 40 3 9 104 40 4 439124 4€ 014 - 9 123.10 123 42 9 4 n ID - -0- 10 105,10 105,10 1052 236 9 313 $ 40 -ler 3016,10-36,10 96w34(8r9an 21 $ 3 a In -$ 31 4 9 30 4 41 $ 30 $ 1 "10 } 10 107,10103 10 107 VI 4- 3 40 10121,101210382,10 1014382 00 3 1 $ I n.10 44- , -9- , -fr , VG -A- , 4} 0.ID 4- $ 264 3-1.124 $ $ 1007.103721.10 3741 91 9 n 114 $ 40110.30310.301092 10-127,10-127,10-127 22 t 30141,113-14111331,10-1411.12131 22 4 1037.1030210-3722 V3 $ 1...- -9- 40331.11311-404 111 V2 9 10129.10123.11329 22 4€ 30141.110121e83.10141e3122 4€ 103010-38.l0-3249 38 • • i No-- GonocoPhiflips Alaska, Inc Conoeo�'hi I I r p►s Drilling Anti Collision Management • Alaska ik Tolerable Collision adi,elC`larn btOMliarta`c��" '. ;.r` ; k a... a...' .... .. Collision with other laterals in multi-lateral well(A3 with A2,A4 with A3 and A2,D with A4 A3 and A21 Risk Worksheet 4escn ti „c;`4wbp1'•,gflC;ht31tt1e-oilfactorswt t t t t"r'1tt , a tits r :ids attad haat,., ki,. : t ,.,cT,. ,a , . it.„..a,,,mt 1.,,.....;. based on Rev.1-29 Jul 99 Well 1D-143 A3,A4 and D laterals fail anti collision with one another In the horizontal legs of the t well base on WP12. The three upper laterals will be geosteered using periscope so risk of leaving Use this sheet to describe a well Interference scenario where QRA the zone is minimal. There Is no immediate danger to life or impact on the environment If well 1 D- may be applicable.Check first that the scenario really Is different 143 Intersects itself. If ID-143 intersects itself there would be damage to the liner,swell packers ( from those described on existing worksheets: and tracers. No risk of a well control Issue exists because well 111.143 lateral that Is being drilled ".,. s 1 Is above the previous placed laterals(upper laterals have the same or slightly higher PP)and is i x me Nktor n ,rt,,'"% I being drilled from the main bore with kit weight mud in the hole. reFe �+^nq : David Lee oUt¢( OP' 5 Dan Bearden ') ` r y"•. t 4714I57,441', 4 il Do the consequences ®No of collision include a *res Are the Qwo -.;� - consequences risk to personnel or the i',- :....:: J. environment? of collision Major risk m 5 e�of t sk r,� '." ., ° t 0Yes g collisidnand tnet t fIO "1m ' qct pf C Ilii loft l No HSE risks exist with 1D-143 intersecting itself while drilling. An economic concern exists and it would be the cost of damage to the completion $4,000,000 equipment that has already been placed In the lower laterals prior to drilling the upper laterals and the impact It may have on future production from the wet. i If necessary the lateral that had been drilled into can be isolated and production shut off(loss of lateral)which is worst case scenario. 1 The biggest chance of getting"lost"is when crossing faults,there is one fault crossing in 1D-143,but since the lower laterals will have already drilled across fi the fault the exact throw of the fault will be known so the fault crossing can be planned for. If we do get out of zone we can determine what zone we are in based on real time logs and cuttings and then steer back into the correct zone. s .i 1. 1. it l 40d,li pr pillkiois3iifKQ y 15 �eqt $YC= $4,000,000 i tti cahseiue4 e014:4e , t 0113110P2 mgoliwboliosimpitutt, sl h4igio ,4 ax , omi A _ . . i i Is there a practical way 0Yes to substantially reduce i'.Nill'EgilligtkAWNPYbI4 either the probability of ®"0 = *thi.:plarined 4tie11 ,,..} 1 collision or the severity V= $33,529,000 of the consequences? s 1 . eg� a me (ts 'of olt3salt t "Pte.ON MOIONP` I ptahri 411 U17Fiat�� rittcttta ira"kiaY*'' t t f tit*, Il` € ;��� e s�n.��� � s, � t I I i iII you)tepars t d a4r#f?' allitan$ �+ t not 1 til t t7II ,i t t t a r + I F 0.01 i. y sgpt 'tl1 tot l &e a i, `itIM1 a e 'olP: V= $0 ' xrfhe� xlscrk� mgaz V F/C= 0.0838225 i 1 t �. k If V F > 1 then dose approach tolerances need not be set �1uen�h�tiXicettatraty-tn`ftt�,;�bov�es�t`�1,a"t�sti'��4�` , nit << z a, . i C lrlanytt m,st3l e�s0vings f ode il l i fto2 r tf t fig=r. It V F t 1e rliK640146.011t; 11001 6141l4N0.0) r C < 1 then Tolerable Collision Risk=1 in C/V F 3 M= 20 F= 1/M= 0.05 ' Tolerable Collision Risk= 1 in 12 is k It Il II III I II • �/ GonocoPhillips Alaska, Inc Conoci i hillips Drilling Anti Collision Management Alaska • A Tolerable Collision canettdfiam3lxsittum_.aitakg,m4 r,�,;, }, ',,..,.:0 .,,t... . .,r,, Collision of the A3 lateral of 10-143 with the existing dual lateral 1C-109(Laterals In the B and D sands) i Risk Worksheet t)escflptloii , t04xx4.a01l� r� ► 0 ° �1 �llltft „3 ..i: diorie7iaiititoviaj m ak:."aa.0r tx6 :. I L o »3ah,,iaii0±11 a„fka i based on Rev.1-29 Jul 99 Well 1D-143 A3 lateral fall anti collision with 1C-109 and 1C-109L1 based on WP12. The A3 lateral will be geosteered using periscope so risk of leaving the zone is minimal. This is important Use this sheet to describe a wet interference scenario where QRA as 1C-109 has laterals in the D and B sands. There Is no Immediate danger to life or Impact on may be applicable.Check first that the scenario really Is different t the environment ifwet 1D-143 intersects 1C-109. If 1D-143 intersects 1C-109 there would be from those described on existing worksheets. / \ \ damage to the liner of 1C-109 and possibly reduced production along with having to plug back the S 1 i 1 a lateral we are currently drilling and sidetracking. No risk of a well control issue exists because if E a+ n 1C-109 is hit,we would be colliding with the well with kill weight fluid In the hole. e , rep red by , David Lee n. f g00ett,b�; Dan Bearden tlf VP .t w 7;7., Do the consequences fo )rcaOno % risk to personnel or the consequences environment? of collision Major risk : . V 9k ''4st'altthe cohsequeftces2lf z yk k,afi a -1. ) °Yes G61111ot1 at d°tht' eCessaty , �tn laj 4'iGEIUf}u �3i�.W C?i i 5 Mar''atx' Cost bf�'`rQloign : No HSE risks exist with 10-143 intersecting 1C-109 while drilling as 1C-109 would be intersected at a depth with kill weight mud In the hole. An economic $4,000 ,000 concern exists and it would be the cost of plugging back and sidetracking the lateral that we are drilling as well as damage to the lower completion in le- 109 and the potential loss of production of 1C-109. 1 The only way we will hit 1C-109 is if we get out of the A3 sand while drilling the A3 lateral. The chance of this is very low as we will be geosteering the well with periscope and If we are approaching exiting the sand we will turn in a manner to stay In the A3 sand. I I 3 s JJ S i' E t(t'#F t:-tht3 i4 b t k Bot 0,1ih�0]'obrrJi of Aat(lslota gtri igaiiy ; i. to 4 4f o C= $4,000,000 t efi4 ihe6ddttseque lCes be reducevif How4tlrgtttthis ; .;.collision w« I�F.M�,: 1 Is there a practical way OYes to substantially reduce No ttma a the NI'V tkf t 1 either the probability of �,t. ill i.a4 ted w+;1 r collision or the severity V= $33,529,000 of the consequences? - 7.a 7 it .�4 r ^c>� a n '� s XaWtrn9 jin.ew sit of go rsipn loll dila: tPi � ' lat i'ike11+ 11 k t 'eduction;air a#ra k n of e tottl, iPorQa E ybu p0pareri1Mo eret'e? Godetlne; tJ tib "�c ,i x=1 k t ��C .,� . .�... -.ter_ r F= 0.01 1 • Witilitk4$f,!b W1tfeSiTglgejp 4d V= $0 • f gI��f. ill t w V F/C= 0.0838225 s 1 If V F e 1 then close approach tolerances need not be sat Olirett t1e EMZzi aitit�tta9t4e ebo+Ee�s tmt.iir i� #i+ +ii' , e 24.1de�E6°3v�i a ekfl 1 t tied s[*+��4 F ext r�E7 a ) r C - , ilAtt �'�,fl ; Stilltt4Ori ki tadB 0111 t1Of r!BI1G01 i g It V F 't the i'4�C`ttat 1 t7i3 ' G!<11d 1rr tkri'2t1 l C < 1 then Tolerable Collision Risk=1 in C I V F ', [..at i..?E Ll. t,FMv,'+rd .1..t.IS�YNIIt S1 QFC a.45 d.'en5 M= 20 . 1 F=1/M= 0.05 ' Tolerable Collision Risk= 1 in 12 1 1 I 1.y t 1 1 . . f '-‘40.--/ ConocoPhillips Alaska, Inc Conor hiI I i pS Drilling Anti-Collision Management Alaska • • ,,enG, 'a $'.it3t,;e4''Pt�l'�dtY' 7�i'ii° ..w' ��`�t�. jw'.v:,.s 1, ry,- a��i�SS.:�,.a.:t: sitik sk.rf.: r.U1y�h',i it\ Tolerable Collison Collision of the A2,A3,A4 and D laterals of 1D-143 with the existing dual lateral 10-140 (Laterals In the B and D sands Risk Worksheet Descnptr©bt3eeatiattndrue r scut 11'Rh fet':eil? uosle otibr�fl$`t , �i 1 spd�ie�li .ihe ky . r,x�..:. ol s;ie.: , based on Rev.1-29 Jul 99 Well 1D-143 A2,A3,A4 and D laterals fail anti collision with 1D-140 and 1D-140L1 based on WP12. The three lower laterals(A2,A3 and A4)will be geosteered using periscope so risk of Use this sheet to describe a well interference scenario where ORA leaving the zone is minimal. This Is important as 1D-140 has laterals in the D and B sands. The may be applicable.Check first that the scenario really Is different 1D-143 D lateral when drilled will be closely monitored for magnetic interference,if interference is from those described on existing worksheets. picked up we will assume we are approaching 1D-140 and we will drill away from the well. There (/,` 1 Is no immediate danger to life or impact on the environment If well 1D-143 Intersects 1D-140. If t r� 1D-143 intersects 1D-140 there would be damage to the liner of 1D-140 but this well is currently Pr pained by ) David Lee ,/, -.:7-r-k'\ suspended welting abandonment so the only cost Impact would be to plug back the lateral we are �lttfhortzetl by Dan Bearden qty`4 currently drilling. No risk of a wet control issue exists because wet 1D-140 is shut in awaiting 1 'sr, abandonment. i �`x .er•m.- rl' a P , Do the consequences Are the fog° of collision include a *yes C"0il risk to personnel or the consequences i environment? of collision . Major risk a 21.01#116601014201-VM - Yes . df tt�C�§j nl^�SNe Fah'�; t, r,¢6 1�"t'�I :0 61i e4 :4 143eu PSit 1' ' t�rrf Itll actttln �� ��t,d, "Si I'f I`.. ... r _ ? i,-.,. ...ti. ,,.,,,... ,,. ..,m.,. ,kit Cost of Co111sio0 4 No HSE risks exist with 10-143 intersecting 10-140 whae draing as 1D-140 is shut in awaiting abandonment. An economic concern exists and it would be $750,000 the cost of plugging back and sidetracking the lateral that we are ddltng. il 1 1 t t 's t Y. n t , ��,�„n �a� � im;,te tot los#�f Ho#},f Ct} lif,#f1e i1}C,4}4bt`f,,t'.G4�Ilato}h 0 fke seveA C= $750,000 83f"fie*SSO4S t S � + might this a i ,� ..,CST U fora mai 5l'iita ikddllfng 4p�ira ott*Ark s c ;t gI Is there a practical way stlmete the NPi/of 1 Ares to substantially reduce 0) ,) r x z either the probability of 4_ 4the"planned we11 j collision or the severity V= $33,529,000 a of the consequences? fi 2 T c400feskorslory (lit aVOO 041 01iF t' i041-e.wgareaion;as a rcinofih611 uili • op46. 4 0#10 001 ,3itar + F= 0.01 -00:::.friatei*tdtai coat bf •Kt`hstgritfArikrMuctri V= $0 • it the ns 7"t^`}TM3 n ° V F/C= 0.447053333 0190tl '1€iYi 0,0�y 4ti`the 8tip`re OkriateS tttt3W' If V F - 1 then close approach tolerances need not be set {5 c t c �n ,E C Iftarl it ie t13t18 the Sdi7fngs made trf5r 1 itbt t dlic1h f v F ., ttaetlfsS'l tftkie lite fttttelt7 Gilltroe ne 4 r P c < 1 then Tolerable Cotlislon Risk=1 In CI V F M= 20 F=1 /M= 0.05 ' Tolerable Collision Risk= 1 in 2 t i t ii 2 i t t 1 ill 411 1 I , ConocoPhillips ConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska I i Tolerable Collision Oenentifiame.otrseenano ;. ,; '., .'.:,, k' t. .. Collision of the A4 and D laterals of 1D-143 with the planned single B lateral 1D-145 Risk Worksheet fefip'llan {Baswtl+;tdrttoepsftar �rnlcnot2ect.elt3srttff �uf�osrtm t 4_,rh ._ ,aostbf:r �n4'ijte�3sk} ",.....,:; ,,a.,, .?,, <,,�:� ,.�,' i ;,#.€,�:.x...4159, e based on Rev,1-29 Jul 99 Well 1D-143 A4 and D laterals fail anti collision with the planned well 10-145 based on WP12. The A4 and D lateral will be geosteered using periscope so risk of leaving the zone is minimal. This is I Use this sheet to descrbe a well Interference scenario where QRA important as 1D-145 will have a lateral In the B sand. There Is no immediate danger to life or ii may be applicable.Check first that the scenario really is different impact on the environment if well 113-143 intersects 1D-145 as 1D-145 will not have been drilled ii from those described on existing worksheets ` yet. If 1 D-143 Intersects 1 D-145 there will be zero damage and cost impact,1 0-145 would have ii 4 `'t 1 to be re-planned directionally before it is drilled. No risk of a well control issue exists because well �l 1341Jut E i x a `�- •}7 s 10-145 will not yet be drtled. l' . Y David Lee , s , ( d t��.._ h' ..0 7 4 Dan Bearden ";, , I i q� t d�� Do the consequences ll •No of collision include a ®Yes Are the oNe risk to personnel or the consequences i of collision environment? ':-',_ Major' risk 1 113101111410.40:04000,101:` F :f1,�k`,„,.ds ids�", oyes 10,,4005.1.. 6 k .04i rlt tHlttoo t rkniedtalradtion,I tETM r tl e:1411101 frir iritst.tf G lswn . \tv uw,(n.F.o 1'P7,,,,, Phh i.i:A4 mrw lEN:.3 I:t No HSE risks exist with 10-143 Intersecting 1D-145 while drilling as 1D-145 will not have been drited yet- Na economic concern exists as If we intersect the $100,000 i planned line,10-145 will just have to be re-planned. g v The only way we will intersect the planned line of 1D-145 is if we drill out of zone while drilling the A4 and D laterals. The chance of this Is very low as we will be geosteering the well with periscope and if we are approaching exiting the sand we will turn In a manner to stay in the A4 and D sand. I uow oufdrthet ohablEiity t�soilixionnortipl,he3severttg r p.§ttfnate�xthe total post of £ �� E t , �„l;r � .��histen c= $100,000 t�� li+ , 4 f' ?? itis w r Ir as lfie� IGrigioperatipsw kI*w r r n rd st i,n g 1 41,R w ,r_, „rc d.tmgo,y is s i wms:;3a iA ,s,u.fu iJ .h'a i..li „n alas �, i6 I1 4 Is there a practical way bm i o <`�`EsimatetheMIX yes to substantially reduce No MIXli ON the probability of thin tinned Welt se Pii collision or the severity V= $33,529,000 ri of the consequences? - I, ♦ f , CCepti to+ffntte Tt k`of collision 1nti11 reduce the JP t of the, a planrled trreil What rediiicti 7n�as a fracfion o tht3 to#at hlRt{,are �!$1,1.I f}r pared jb R, le` (l turlglftt@•.:.It}05 ., na. h 3�a3tt .nkt1"fi'41{+hLik_t 4 F= 0.01g. 'e stimate ttteLlott toast f 4.4 -ir1staritla93)redt,Xcln t / V= $0 ,; Etre risk . , V F/C= 3.3529 i r h nsa e P4N e, ; nM If V F > 1 then close approach tolerances need not be settv�nflauncsrtatnty>tza,aeolf�� tiaes� tt,tw� �; fel 4 V Y P n"xfi ,d,t k9 rp If V F 1 the.risk tfulwelgh+heInsk Ince' g4*41lne, 4: s C < I then Tolerable Collision Risk=1 in C/V F M= 20 . close approach tolerances need not 1 F= 1/M= =0.05 Tolerable Collision Risk= be set I i i s �r t t K 445 LL1 gii9 p 1 D-143L3wp12. 1 6.412 Plan Su ' mary SURVEY PROGRAM epth From Depth To Survey/Plan Tool 28.00 1000.00 1D-143wp12.1 (Plan: 1D-143) GYD-GC-SS • 1000.00 2369.47 1D-143wp12.1 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC �:� 1I�` 2369.47 4309.00 1D-143wp12.1 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC Ii '� 4309.00 4600.00 1 D-143L3w 12.1 (Plan: �i� ' '"�` P 1D-143L3) INC+TREND �� /� -���� 4600.00 6100.00 1D-143L3wp12.1 (Plan: 1D-143L3) MWD �� �i1`\�� ./ \\\ 4600.00 9090.13 1D-143L3wp12.1 (Plan: 1D-143L3) MWD+IFR-AK-CAZ-SC �,Illli'��'\��� CASING DETAILS grAl I WI AKIMBO I t ---------- TVD MD Name Size `F)7 1'; S 9 DI 1 0-1 43L3wp1 2. 1 6.414 Plan Summary SURVEY PROGRAM epth From Depth To Survey/Plan Tool 28.00 1000.00 1D-143wp12.1 (Plan: 1D-143) GYD-GC-SS 1000.00 2369.47 1D-143wp12.1 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC 2369.47 4309.00 1D-143wp12.1 (Plan: 1D-143) MWD+IFR-AK-CAZ-SC 4309.00 4600.00 1D-143L3wp12.1 (Plan: 1D-143L3) INC+TREND MN 4600.00 6100.00 1D-143L3wp12.1 (Plan: 1D-143L3) MWD / 4600.00 9090.13 1 D-143L3wp12.1 (Plan: 1D-143L3) MWD+IFR-AK-CAZ-SC CASING DETAILS p.. ,t � .• .... TVD MD Name Size �'M ' 2343.70 2369.47 13-3/8"x16" 13-3/8 3693.26 4584.56 9-5/8"x 12-1/4" 9-5/8 3726.70 9090.13 4-1/2"x 6-3/4" 4-1/2 p ' I 10 I ! ! ! I 9-5/8"x 12-1/4" 0 0 13-3/8"x16" ▪5 -� 5 44°E r g - - - - 2000 9-5/8"x 12-1/4" 4-1/2"x 6-3/4" T8016" o o o m 0r p 0..,,Ooam o© o o °� 1 � - V) aM mm m m 0 1 1 -f I f I I I I I i I f 0 a.. 0 2500 5000 7500 0 850 1700 2550 3400 4250 5100 5950 Measured Depth Horizontal Departure 1�-1a3 9291 0 330 30 O 1 -4200 ro E▪l 60- _ -_- i .oro m -4600 - 4400 - 4500 3 - - _- __ -_ _ 300 60 _ ro620 1 D-145wp05 ' -4202 -5200 °900 P2 f c d 0 30- 2>0 , 4425 so El' 1 2200 - 6500 8500 _ 6700 m 240 120 U - 1 . - rood rano 8. • 0 0 ' I 11 OOI 1 12000' 1 13 1 I 14 00 r 15 00 1 1 60001 1 170 ' r ' ' I 1 ' I ' 1� __- .n ro - ,5ro • s• ei7200 -7202 210 I ,s 00 8000 9000 n.nt2.,u�2, - 85,10 180 _.00 SECTION DETAILS aero 0265 - ...c MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target - 1 4309.00 76.56 352.80 3661.59 3562.89 1154.84 238.96 5960276.61 1700931.67 0.00 0.00 1154.84 2 4325.50 78.80 352.80 3665.11 3566.41 1170.83 236.94 5960292.58 1700929.52 13.56 0.00 1170.83 3 4355.50 78.80 352.80 3670.94 3572.24 1200.03 233.25 5960321.75 1700925.60 0.00 0.00 1200.03 4 4584.56 90.00 352.80 3693.26 3594.56 1425.84 204.73 5960547.30 1700895.27 4.89 -0.01 1425.84 5 4614.56 90.00 352.80 3693.26 3594.56 1455.61 200.97 5960577.03 1700891.27 0.00 0.00 1455.61 6 4653.74 91.17 352.71 3692.86 3594.16 1494.46 196.03 5960615.84 1700886.02 3.00 -4.25 1494.46 7 5617.22 91.17 352.71 3673.15 3574.45 2449.96 73.85 5961570.24 1700756.19 0.00 0.00 2449.96 8 5777.10 87.00 355.08 3675.70 3577.00 2608.87 56.86 5961728.99 1700737.92 3.00 150.44 2608.87 1D-143 0-Lat MW 02May14 CP1 S_flt 9 5888.99 83.64 355.09 3684.83 3586.13 2719.96 47.30 5961839.99 1700727.47 3.00 179.90 2719.96 0 6036.25 83.64 355.09 3701.13 3602.43 2865.78 34.76 5961985.69 1700713.77 0.00 0.00 2865.78 1 6273.58 89.80 358.67 3714.70 3616.00 3102.22 21.89 5962222.00 1700699.00 3.00 30.29 3102.22 1D-143 0-Lat MW 29Jan14 CP2 N_flt 2 6287.79 90.08 358.67 3714.71 3616.01 3116.42 21.56 5962236.19 1700698.56 2.00 -0.53 3116.42 3 7773.28 90.08 358.67 3712.54 3613.84 4601.51 -12.99 5963720.82 1700652.10 0.00 0.00 4601.51 4 7808.48 89.38 358.67 3712.70 3614.00 4636.70 -13.81 5963756.00 1700651.00 2.00 179.79 4636.70 10-143 D-Lat MW 29Jan14 CP3 5 8749.74 89.38 17.50 3723.00 3624.30 5564.37 117.94 5964684.60 1700775.29 2.00 90.11 5564.37 6 9090.13 89.38 17.50 3726.70 3628.00 5888.99 220.27 5965010.00 1700875.00 0.00 0.00 5888.99 1D-143 D-Lat MW 29Jan14 CP4 TD DB Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 TM Depth Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Magnetic Model Date: 13-Jan-14 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.64° North /Y: 5959120.00 Ground Level/Mud Line: 70.70 To convert a Magnetic Direction to a True Direction,Add 19.64°East East/X: 1700702.00 Rig: Doyon 141 GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference i410 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-143 Plan: 1D-143L3 Plan: 1 D-143L3wp12.1 Failed Anti-Collis', Plan Summary TCS, required 19 September,2014 Failed Anti-Collision for 1D-140, 1D-140L1, 1D-145 wp05. TCR required. s s Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp12.1 Database: EDM Alaska Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 113 Pad,KRU Site Position: Northing: 5,959,421.20 usft Latitude: 70°18'0.267 N From: Map Easting: 1,701,118.42 usft Longitude: 149°30'30.085 W Position Uncertainty: 0.00 ash Slot Radius: 36" Grid Convergence: 0.46° Well Plan:1D-143 Well Position +N/-S 0.00 usft Northing: 5,959,120.00 ask Latitude: 70°17'57.337 N +El-W 0.00 usft Easting: 1,700,702.00 ash Longitude: 149°30'42.296 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 70.70 usft Wellbore Plan:1D-143L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°I InT) BGGM2013 1/13/2014 19.64 80.91 57,615 Design 10-143L3wp12.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,309.00 Vertical Section: Depth From(TVD) +NI-S +El-W Direction ia.,,y. p �= ,. . .;, : .�_ .a.". (usft) (usft) (usft) p) 28.00 0.00 0.00 0.00 F',,,2 COMPASS 5000.1 Build 61 . • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28©98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3wp12.1 Database: EDM Alaska Prod Survey Tool Program Date 9/19/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,000.00 1D-143wp12.1(Plan:1D-143) o GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,369.47 1D-143wp12.1(Plan:1D-143) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,369.47 4,309.00 1D-143wp12.1(Plan:1D-143) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,309.00 4,600.00 1D-143L3wp12.1(Plan:1D-143L3) INC+TREND Inclinometer+known azi trend 4,600.00 6,100.00 1D-143L3wp12.1(Plan:1D-143L3) MWD MWD-Standard 4,600.00 9,090.13 1D-143L3wp12.1(Plan:1D-143L3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°( (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (usft) 4,309.00 76.56 352.80 3,661.59 3,562.89 0.00 0.00 5,960,276.61 1,700,931.67 7.06 2.10 Start Build 13.56 4,325.50 78.80 352.80 3,665.11 3,566.41 13.56 0.00 5,960,292.58 1,700,929.52 7.79 2.07 Start 30.00 hold at 4325.50 MD 4,355.50 78.80 352,80 3,670.94 3,572.24 0.00 0.00 5,960,321.75 1,700,925.60 16.42 2.49 Start DLS 4.89 TFO-0.01 4,400.00 80.97 352.80 3,678.75 3,580.05 4.89 -0.01 5,960,365.16 1,700,919.76 32.83 3.41 4,500.00 85.86 352.80 3,690.21 3,591.51 4.89 -0.01 5,960,463.57 1,700,906.53 71.88 9.57 4,584.56 90.00 352.80 3,693.26 3,594.56 4.89 -0.01 5,960,547.30 1,700,895.27 4,366,362,716.42 4,366,362,716.43 Start 30.00 hold at 4584.56 MD-95/8"0 12-1/4" 4,600.00 90.00 352.80 3,693.26 3,594.56 0.00 -0.01 5,960,562.60 1,700,893.21 4,648,267,703.51 4,648,267,703.52 4,614.56 90.00 352.80 3,693.26 3,594.56 0.00 0.00 5,960,577.03 1,700,891.27 4,708,698,160.04 4,708,698,160.06 Start DLS 3.00 TFO-4.25 4,653.74 91.17 352.71 3,692.86 3,594.16 3.00 -4.25 5,960,615.84 1,700,886.02 4,708,692,719.33 4,708,698,160.06 Start 963.48 hold at 4653.74 MD 4,700.00 91.17 352.71 3,691.91 3,593.21 0.00 -4.25 5,960,661.67 1,700,879.79 4,708,692,719.33 4,708,698,160.06 4,800.00 91.17 352.71 3,689.86 3,591.16 0.00 0.00 5,960,760.73 1,700,866.31 4,708,692,719.33 4,708,698,160.06 4,900.00 91.17 352.71 3,687.82 3,589.12 0.00 0.00 5,960,859.79 1,700,852.83 4,708,692,719.33 4,708,698,160.06 5,000.00 91.17 352.71 3,685.77 3,587.07 0.00 0.00 5,960,958.84 1,700,839.36 4,708,692,719.33 4,708,698,160.06 5,100.00 91.17 352.71 3,683.73 3,585.03 0.00 0.00 5,961,057.90 1,700,825.88 4,708,692,719.33 4,708,698,160.06 9/1912014 9:59:51AM Page 3 COMPASS 5000.1 Build 61 . • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3wp12.1 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) 1°) (°) (usft) (usft) (°1100usft) 1°) (usft) (usft) (usft) (usft) 5,200.00 91.17 352.71 3,681.68 3,582.98 0.00 0.00 5,961,156.96 1,700,812.41 4,708,692,719.33 4,708,698,160.06 5,300.00 91.17 352.71 3,679.64 3,580.94 0.00 0.00 5,961,256.02 1,700,798.93 4,708,692,719.33 4,708,698,160.06 5,400.00 91.17 352.71 3,677.59 3,578.89 0.00 0.00 5,961,355.07 1,700,785.46 4,708,692,719.33 4,708,698,160.06 5,500.00 91.17 352.71 3,675.55 3,576.85 0.00 0.00 5,961,454.13 1,700,771.98 4,708,692,719.33 4,708,698,160.06 5,600.00 91.17 352.71 3,673.50 3,574.80 0.00 0.00 5,961,553.19 1,700,758.51 4,708,692,719.33 4,708,698,160.06 5,617.22 91.17 352.71 3,673.15 3,574.45 0.00 0.00 5,961,570.24 1,700,756.19 4,708,692,719.33 4,708,698,160.06 Start OLS 3.00 TFO 150.44 5,700.00 89.01 353.94 3,673.02 3,574.32 3.00 150.44 5,961,652.37 1,700,745.91 4,707,769,685.21 4,708,698,160.06 5,777.10 87.00 355.08 3,675.70 3,577.00 3.00 150.45 5,961,728.99 1,700,737.92 4,704,970,485.61 4,708,698,160.06 Start OLS 3.00 TFO 179.90 5,800.00 86.31 355.08 3,677.04 3,578.34 3.00 179.90 5,961,751.75 1,700,735.78 4,704,966,389.20 4,708,698,160.06 5,888.99 83.64 355.09 3,684.83 3,586.13 3.00 179.90 5,961,839.99 1,700,727.47 4,704,950,381.20 4,708,698,160.06 Start 147.26 hold at 5888.99 MD 5,900.00 83.64 355.09 3,686.04 3,587.34 0.00 0.00 5,961,850.89 1,700,726.45 4,704,950,381.20 4,708,698,160.06 6,000.00 83.64 355.09 3,697.12 3,598.42 0.00 0.00 5,961,949.83 1,700,717.14 4,704,950,381.20 4,708,698,160.06 6,036.25 83.64 355.09 3,701.13 3,602.43 0.00 0.00 5,961,985.69 1,700,713.77 4,704,950,381.20 4,708,698,160.06 Start DLS 3.00 TFO 30.29 6,100.00 85.30 356.05 3,707.27 3,608.57 3.00 30.29 5,962,048.91 1,700,708.36 4,701,107,198.28 4,708,698,160.06 6,200.00 87.89 357.56 3,713.22 3,614.52 3.00 30.19 5,962,148.51 1,700,702.01 4,692,437,295.76 4,708,698,160.06 6,273.58 89.80 358.67 3,714.70 3,616.00 3.00 30.10 5,962,222.00 1,700,699.00 4,684,008,114.47 4,708,698,160.06 Start DLS 2.00 TFO-0.53 6,287.79 90.08 358.67 3,714.71 3,616.01 2.00 -0.53 • 5,962,236.19 1,700,698.56 4,684,029,990.33 4,708,698,160.06 Start 1485.49 hold at 6287.79 MD 6,300.00 90.08 358.67 3,714.70 3,616.00 0.00 0.00 5,962,248.40 1,700,698.17 4,684,029,990.33 4,708,698,160.06 6,400,00 90.08 358.67 3,714.55 3,615.85 0.00 0.00 5,962,348.34 1,700,695.05 4,684,029,990.33 4,708,698,160.06 6,500.00 90.08 358.67 3,714.40 3,615.70 0.00 0.00 5,962,448.28 1,700,691.92 4,684,029,990.33 4,708,698,160.06 6,600.00 90.08 358.67 3,714.26 3,615.56 0.00 0.00 5,962,54823 1,700,688.79 4,684,029,990.33 4,708,698,160.06 6,700.00 90.08 358.67 3,714.11 3,615.41 0.00 0.00 5,962,648.17 1,700,685.66 4,684,029,990.33 4,708,698,160.06 9/19/1014 9:59:51AM Page 4 COMPASS 5000.1 Build 61 0 • 1 • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp12.1 Database: EDM Alaska Prod Planned Survey - - MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) „ p) (usft) (usft) (usft) (usft) 6,800.00 90.08 358.67 3,713.96 3,615.26 0.00 0.00 5,962,748.11 1,700,682.54 4,684,029,990.33 4,708,698,160.06 6,900.00 90.08 358.67 3,713.82 3,615.12 0.00 0.00 5,962,848.05 1,700,679.41 4,684,029,990.33 4,708,698,160.06 7,000.00 90.08 358.67 3,713.67 3,614.97 0.00 0.00 5,962,947.99 1,700,676.28 4,684,029,990.33 4,708,698,160.06 7,100.00 90.08 358.67 3,713.52 3,614.82 0.00 0.00 5,963,047.93 1,700,673.16 4,684,029,990.33 4,708,698,160.06 7,200.00 90.08 358.67 3,713.38 3,614.68 0.00 0.00 5,963,147.87 1,700,670.03 4,684,029,990.33 4,708,698,160.06 7,300.00 90.08 358.67 3,713.23 3,614.53 0.00 0.00 5,963,247.82 1,700,666.90 4,684,029,990.33 4,708,698,160.06 7,400.00 90.08 358.67 3,713.08 3,614.38 0.00 0.00 5,963,347.76 1,700,663.77 4,684,029,990.33 4,708,698,160.06 7,500.00 90.08 358.67 3,712.94 3,614.24 0.00 0.00 5,963,447.70 1,700,660.65 4,684,029,990.33 4,708,698,160.06 7,600.00 90.08 358.67 3,712.79 3,614.09 0.00 0.00 5,963,547.64 1,700,657.52 4,684,029,990.33 4,708,698,160.06 7,700.00 90.08 358.67 3,712.64 3,613.94 0.00 0.00 5,963,647.58 1,700,654.39 4,684,029,990.33 4,708,698,160.06 7,773.28 90.08 358.67 3,712.54 3,613.84 0.00 0.00 5,963,720.82 1,700,652.10 4,684,029,990.33 4,708,698,160.06 Start DLS 2.00 TFO 179.79 7,800.00 89.55 358.67 3,712.62 3,613.92 2.00 179.79 5,963,747.52 1,700,651.26 4,684,013,387.21 4,708,698,160.06 7,808.48 89.38 358.67 3,712.70 3,614.00 2.00 179.79 5,963,756.00 1,700,651.00 4,684,008,114.47 4,708,698,160.06 Start DLS 2.00 TFO 90.11 7,900.00 89.38 0.50 3,713.69 3,614.99 2.00 90.11 5,963,847.49 1,700,649.60 4,666,235,867.67 4,708,698,160.06 8,000.00 89.37 2.50 3,714.78 3,616.08 2.00 90.09 5,963,947.45 1,700,651.42 4,641,372,328.87 4,708,698,160.06 8,100.00 89.37 4.50 3,715.88 3,617.18 2.00 90.07 5,964,047.29 1,700,656.72 4,610,853,300.96 4,708,698,160.06 8,200.00 89.37 6.50 3,716.98 3,618.28 2.00 90.05 5,964,146.88 1,700,665.51 4,574,715,966.71 4,708,698,160.06 8,300.00 89.37 8.50 3,718.07 3,619.37 2.00 90.03 5,964,246.11 1,700,677.76 4,533,004,361.48 4,708,698,160.06 8,400.00 89.37 10.50 3,719.17 3,620.47 2.00 90.00 5,964,344.84 1,700,693.48 4,485,769,319.53 4,708,698,160.06 8,500.00 89.37 12.50 3,720.27 3,621.57 2.00 89.98 5,964,442.97 1,700,712.62 4,433,068,411.92 4,708,698,160.06 8,600.00 89.37 14.50 3,721.37 3,622.67 2.00 89.96 5,964,540.37 1,700,735.18 4,374,965,876.09 4,708,698,160.06 8,700.00 89.38 16.50 3,722.46 3,623.76 2.00 89.94 5,964,636.93 1,700,761.13 4,311,532,537.32 4,708,698,160.06 8,749.74 89.38 17.50 3,723.00 3,624.30 2.00 89.92 5,964,684.60 1,700,775.29 4,278,019,900.16 4,708,698,160.06 Start 340.39 hold at 8749.74 MD 8,800.00 89.38 17.50 3,723.55 3,624.85 0.00 0.00 5,964,732.65 1,700,790.01 4,278,019,900.16 4,708,698,160.06 9/192014 9:59:51AM Page 5 COMPASS 5000.1 Build 61 • 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1 D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1 D-143L3 Survey Calculation Method: Minimum Curvature Design: 1 D-143L3wp12.1 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) 1°) 1% (usft) (usft) (°hoousft) .m...l°) (usft) (usft) (usft) (usft) 8,900.00 89.38 17.50 3,724.63 3,625.93 0.00 0.00 5,964,828.25 1,700,819.31 4,278,019,900.16 4,708,698,160.06 9,000.00 89.38 17.50 3,725.72 3,627.02 0.00 0.00 5,964,923.84 1,700,848.60 4,278,019,900.16 4,708,698,160.06 9,090.13 89.38 17.50 3,726.70 3,628.00 0.00 0.00 5,965,010.00 1,700,875.00 4,278,019,900.16 4,708,698,160.06 TD at 9090.13 9/19/2014 9:59-51AM Page 6 COMPASS 5000.1 Build 61 ! • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1D-143 Project: Kuparuk River Unit TVD Reference: Plan:70.7+28 @ 98.70usft(Doyon 141) Site: Kuparuk 1D Pad MD Reference: Plan:70.7+28 @ 96.70usft(Doyon 141) Well: Plan:1D-143 North Reference: True Wellbore: Plan:1D-143L3 Survey Calculation Method: Minimum Curvature Design: 1D-143L3wp12.1 Database: EDM Alaska Prod Casing Points - - - Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,369.47 2,343.70 13-3/8"x16" 13-3/8 16 4,584.56 3,693.26 9-5/8"x 12-1/4" 9-5/8 12-1/4 'i 9.090 13 3726.70 4-1/2"x 6-3/4" 4-1/2 6-3/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (usft) (usft) (usft) (usft) Comment 4,309.00 3,661.59 1,154.84 238.96 Start Build 13.56 4,325.50 3,665.11 1,170.83 236.94 Start 30.00 hold at 4325.50 MD 4,355.50 3,670.94 1,200.03 233.25 Start DLS 4.89 TFO-0.01 4,584.56 3,693.26 1,425.84 204.73 Start 30.00 hold at 4584.56 MD 4,614.56 3,693.26 1,455.61 200.97 Start DLS 3.00 TFO-4.25 4,653.74 3,692.86 1,494.46 196.03 Start 963.48 hold at 4653.74 MD 5,617.22 3,673.15 2,449.96 73.85 Start DLS 3.00 TFO 150.44 5,777.10 3,675.70 2,608.87 56.86 Start DLS 3.00 TFO 179.90 5,888.99 3,684.83 2,719.96 47.30 Start 147.26 hold at 5888.99 MD 6,036.25 3,701.13 2,865.78 34.76 Start DLS 3.00 TFO 30.29 6,273.58 3,714.70 3,102.22 21.89 Start DLS 2.00 TFO-0.53 6,287.79 3,714.71 3,116.42 21.56 Start 1485.49 hold at 6287.79 MD 7,773.28 3,712.54 4,601.51 -12.99 Start DLS 2.00 TFO 179.79 7,808.48 3,712.70 4,636.70 -13.81 Start DLS 2.00 TFO 90.11 8,749.74 3,723.00 5,564.37 117.94 Start 340.39 hold at 8749.74 MD 9,090.13 3,726.70 5,888.99 220.27 TD at 9090.13 Checked By: Approved By: Date: 9/19/2014 9:59•51AM Page 8 COMPASS 5000 1 Build 61 • • I. 0 0 � O =� W LL U 1- Q J a N LL N1 V A9.) 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V' V U) 0 r CO U) U) (0 N r CO (O r V U) U) 0 U) 0 0 r 0 p O C r r N N N N N N N M M M V V 7 V U) U) (O (O r N- o O r r r r r r r r r r r ,- r r r r r r r r U a• a W 0 o co n N CO J 6M) 6o N > CO �\V .`I3 "6 co CO r W r N CO f� U) V I� M r 0 co N- U1 (NI 0) CO V' a' CO CO d 7 O) U) r O O) N- V 7 r I` M O O U) r O O N CO U) -4- 01 N N 3 (U U) CO CO U) r U) I� CO I- M CO N a) CO CO U) CO U) N 6) r + + U Y CO N- U) U) U CO M N N 0 0 6) O) 0) O) 0) CO co CO N- E I- r < as N- N- N r N r N N r V N r r (O co co (O co co co co co m o o c O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CL r` n -E Q '. C 0 N 0 N 0 0 0 0 0 0 0 0 0 0 N r r co I N- N N- ':') a (a (0 3 •C at i r ,- r r r r r r r r r r r r r r r r r r r d d H 2 W W I- CO a) V I- O) U) C) 0) CO 6) r r co a) O V CO CO I- U) O N M O) N- C) CO CO (O W U) 0 V CO N N o U) V M O N CO W O 6) U) CO CO N (O CO CO CO CO CO CO CO d co U) U) r U) N U) CO U) V CO 7 7 N CO V V V' V [t 'Q 4 U 27 Of M d' U)_ U) CO N I� 07 CO a) a) O r N N N CO V U) CO f- CO 0 C r N N N N N N N N N N N Y t (0 (0 (0 co co co co CO CO CO (0 (0 (0 CO co co co (O CO (0 CO CO UI O) O) O) O) 6) a) 6) 6) 0) O) W 0 W a) 6) a1 0) 6) 03 6) O) 6) R 2 z a) = O v () v d O O0 0 0 0 U) O O O O O 6) 6) O CO 0 0 0 0 0 0 0 = C V O O O O V 4d) a) co O O N r r U) O O O O O O O N w N O O O O O O 6) O) O O O O O O o O O O O O O O O .2 y al U H 6 U) N- N CO CO CO U d w re m z y a) O G p 0 3 0 li `-' 31- g zu) a F 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O M M M M O O O M M M N O O O O O O O co E y O 7 J 0 co a ; ... co a W U) 0 U) N 0 V CO V N CO N- N 0 0 U) 0 (O CO N CO CO CO V CO O CO r M V 7 U) U) 0 0 O CO N. U) V N _ CO (O V V [T N- O (O N. CO N O V (O (O (O U) U) U) U) U) U) N I,- N- N- N- N- N- r M CO a) 0 0 r r r r a N U) U) co U) U) U) (O U) U) U) CO (O CO (O CO CO CO CO (O (O CO CO N CO ^ CO M M M M M M CO- M M M M M M CO- M M M M M M M 0) U) O U) N 0 7 CO V N CO N- N 0 O U) 0 (0 _ (O N U) U) U) O n O CO 0 N N N- r I- U) V N a) CO N- U) M M M U) r V (O r N- M V V V 7 V V a M M ✓ N- n N- N- N- N- CO CO W 0 0 CO CO CO CO CO CO CO CO COO II,- N- N (` r r r r r N r _ co- co- M co- co- M w MM MMMMM MMMMMM_ Y. Z o N d' 0 > d' V CO co co 0) 0) 6) 0) U) CO N- N N- r N- N- N- I` N- N- N I- 0) 0 M 0 0 0 0 0 0 U) <O 0 N-(0 0 (O CO (O CO CO O N N N N M U) N U) U) U) U) U) (O N. CO ' CO CO CO CO CO W W O U) UO co U) U) U) 0 U) U) U) U) U) U) U) U) T U) U) U) U) U) U) U) U) CO M M CO M M M M CO M M M M M N CO CO M CO M M CO M nN 22 Y Q r m J A () OI J C co et N ,- M N- N- N- N- 0 7 a V 7 V 0 W O s- CO 2 CO O (O N W CO N L.- C) co 2 CO (O CO CO CO CO 0 0 0 0 0 0 0 0 co :L-'Q r r r r coO aN { o rOri ai aUN- 60 O 0) O O O O O O O ) 0) a) Cr)) CO CO CCO CO> CO CO CO 0) r.-" a. a) a) a) a) a) a)-O0 n yfa J N V O) 00 0 M 00 a a M C) O U n O T CO N co N L > ,- V V 3 C °v e- e- M 4 CO a Y Y o a _J a a m O O (a OU ` r V LL LL a lL LL a O m N •• • r I- F G F F L O o 7 .0 �a 0 O O .0 O 0 6) U Y Y CL d O O O N M O O M O 6) 0, o O U) M O O CO (4 a) 0 0 0 0 0 0 0 E 0 O 0 N N 0 r (00 O) N 0 0 N (0 O O U) N N- Uf O O O O o o o a >, O O O r J O N- J O 66 O (O J O O M J n a O O O O O O O co a) o o O a O N- a 0 co o O co 0 0 0 N- a co ,_ 0 0 o O o 0 0 c{ co CO (O n I- CO CO 0) 0 0 r N N N CO V U) (fl r CO 6) = Uco Uco tn Ut (n co rcoCoco f. 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H W w co co N N (O 0 V CON N 0 O (O 0) CO V n N- M 0 (O O V 0) 0 00 CO n N (O (O CO O O V V N O6 03 0 CO 0) (O CO N CO . N: n n n n n n n o n m n n n (o m V N6 (O V N6 CO m V V V V V V V V N V O V V 0 V V V V V CO CO CO N N U 21 Ci) d) O N M V LO O n n n O 0) O r N CO V (O O O N- CO 0) N 0 E N M M M M M M M MM co- co- CO V V V V V V V V V V Y L O O O O O O O O O CD O O CO CD CO 0 O CO O CO O O CD O CD y m t 0) 0) 0) 0) co co co C co 0) 0) 0) 0) 0 C O 0) 0) C O O 0) 0) 0) 00-2 1. Ln to- (ri 1. (ri 1. ..0- vi (n ui Lri (ri Lri Lri N vi (n (ri Ln (ri (ri (ri Lri m c d 0 c u ai c /° 'a c c m 7 0 0 0 0 0 0 0 0 0 0) 01 0) n O CO 0 CO CD V N o 0 o ` v o 0 O o 0 0 0 0 o n n 0 0 0 0 0 0) 0) 01 0) 0 0 0 m (0 0 0 0 0 0 0 0 0 0 0) 0) O 0 0 0 0 0 0) 0) 6 0) O 0 0 o w 01 m 0 N n n O C C 0) C 01 O CO 0) 00 U m w K r r TO sz = m .a w u 00 " .R..t Ro -11- aZa ) o � O o 0 0 0 0 o O o O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C� O O O O O O O O O N N N N N N N N N N N N O O O G y 0 = J C U 0 - C Co a n N CO CO O V 0) V V N 0 0) O CO CO N- N- n n CO 0 (O CO N 0 CO CO LO CO N 0 0) CO 01 0 01 0 r N CO V LO CO n CO O 0) O V V V V V V V M M M V V O n O O O N M V V LO n N N N N N N N N N 0) CO CO O CD CD O CD CD O O CD CD CO CO CO CD CO CD O O CO N 07 ^ CO-M CO-M CO- CO- M M M CO CO- CO M CO CO CO M CO- CO CO- CO- CO CO M CO- M Cl. N.- (V CO CO co V O) V V N O O CO O O N- N- N- N- O O Ln CO N O LO CO N O 0) n (O CO CO n CO n 0 01 0 N M V 0 O CON- CO CO CO CO CO N N N N N N CO V LO O O W O N CO M V 6 N N N N N N N N- n n n N- n n N N- I N N- n n n N- N- n n n n n N- n - CO' CO 1111111 COCO M M M : : : : : M : : :Ma0Vn n (0 n n O O O O O O CO O CO 0 CO O R 0 Ln Ln LO LO LO 6 6 (O LO LO Ln LO O O O O O O O O O O O O N V O CO O N V CO n n n n LO CM O CO O CO O COO (O LO LO N (O LO CO r r r r r r r CO CO CO CO CO CO CO N o. Y CIS U J C 0 el CO CO CO O CO CO O CO CO (O O CO n n n N- N- N- n CO O 0 CO O O co a O O 0 C 0 O O O O lO M am CO M M M M CO M M M 2 M CO M .f2 't. O O O O O O O O O O d) Oa; 4) a; m Q) D7 O W 0) d) O O .o 0) m a) m rn m rn rn rn m 0 o CO CO CO CO co co w cooo co ao oo ao N R N n m O. m 0_ M (,)-1 Ti V i.. Of a- at - ? 0 V V 3 c E.. N. o N- :c .a 0) a Y .1c O D J O O m r r 4- F F 'a O 0 0 N N 0 o cs o t 0 Y ye_ 0 o 0 o 0 0 0 o O co ('10 (0 (-40 o 0 0 0 0 00 0 'C mo 0 0 Z 0000000 ON , 04 , 0 00000 000N- '10 00 0- >, 0 0 0 0 0 0 0 O CO J O OD J O O O o 0 0 0 0 0 of . O 0 0 a m O O O O O O O O n 0 0 0 0 0 0 0 0 0 0 0 0 0 V M 0 0 0 O r N CO V LO O n 1--- CO CO 0) O r N CO V LO (O n 1,- CO d) O = 0 n n n ti N- n n n n Yo n n V n 0) co- O 0 O 0 ao co- ro t co- CO m N C . .a --- w CO CO e O. 2 . d C7 C N m c E S °: a/ 4.' d R (� 0 a m 3 3 0 a ORIGINAL • • r-1 { ° $ co / ¥ ; co « \ ( ® / \\ � « ) ) e \ / \\ ,- D 73 ) 2 = \ / \ c{ co � /� � _} ® ° � f / 5 I) ) 5 o ) .t_ 2 ) ] O } {} \0j k ) I-/ § ) k o± E =E ~ E 3 � / C _ o co CO / 0 N. CYi 13 ® G ) e a \ ;c4 C f m co ( \ g ©ai 5 /j \ ? ) } — \ .Ne ) ) w § \ } /) ) \ j \ { ! S « Cs 0 \ . = / \ 0 ai 03 \ kea00a) 2 uaaRRA ; E \ fIrr R ? G ! NAL • • goa ro to of 0 0 N CO CO r T 0 C CO O O 0 O O O n n CO M O O P_' >1:0 7 -cif.O p N 7 a {� 4) N + + (O Y as n n E m a o N- d n n E E SI (tea m 3 .= 0 a. a1- 2 � 5 J ai U -8 c o d .c w d o C v co v it C r co IR d d ID^ C C V ii; CA O E a c ` V = .03 415 E C d o 0 O• d ► w d .c 0) W (° �• O C 2 m CO ro N Q (n 07 J X 2 CO 0 0(u .03 O CO V E c.. LiN 0 0 0 a' O 0 2 2 0) 2 r 0 n rC O co V O ) n O) (O NMV CO NO MN n E (O O co O 6 N NO co N 61r O co O co c0 (- N. CO O co O n Cl)C N 0 .4- 0 /400r300 LL LL a O o (0 0 (0 .6 I- v F- P F- F- u H F- o F H a Lr' 0) O O O o O O O L o o O O.. 6 L c0 ° O -c o o t O o O O o L T O O MV C) co N M N N N M O CO C 7 O J O c. J 6 J J J CO V CO J V O N 00 M o CO 0 a) 0 0 0 0 0 O M E 'C 'C V V C V V r 'C C 'C C 'C C r m >O N o (0 CO CO 06 01 06 CO CO CO 03 CO CU CO CO 06 O 0- O U) U) U) (0 CO CO CO U) U) U) CO U) U) U) CO F- Q Q d Q E (0 V (O co n M (O N O (O O) co 0) V n (0 O CS/ O N n 0) O CO N M n CO (O 0) CO CO N aD N M V O CO M N n V r N M nr O M M M O O 0) n co V M N N r N (0 W d + l6 C 'a 0 V - O` v 0 _ V M M V (D CD n CD CO N N CD n O) N (O M {ti CO CO O CO CO 7 O] CO O n N V (O n M O (O {ti 7 O O (f) (f) 4 O) N 6) CO N N '-- CO V' N )( x )( O (O N O N (O 6) 7 O r (D O O CO CO CO _ J N V V 7 7 (D n W (D (O (O CO bo M N Z c' r r r r r N N N N M M V V (O (O 07 7 + O) r C d O Y CO 0 0 N n n (jN 0) C A w O M N N 0) of CO CO CO CO O M CO 0 V O O O t1 O.�^a co co n co. .r- O N N CO r n Nn n (O n O n N d M N M (p = CO O M M N6 (6 7 CO (- N.- r V V N N6 (O y > 0IL..v.. CD CO N- 0) 6) 0) n n CD O r r N N W N rg ti) N n r n CO(O CO(O CO(O CO(O CO(O( D (D N- Q :!+C ; Q M M M M M M M M M M M M M M M M 0 = (0 "4- N d d a M M (O N M O d (O 0) r LE V V 3 E V V O a r r V r CO (O CO O O O (O (D 7 N O 0) (O N O N N V M • Y Q( Q( J 7 a CO( M O 'p O CO CO (O 00 n N r 0) N CO N- N V n O (Q (p r r V R 7 N Oi P. +t.. 6i (f) ([) V 7 (7 I- r N (O M N M 6 0 O C C r d 7 o N CO N r CO n CO CO n CO N O V O c c a O.��'' co co M Cr) N N N n co O N N n N n O o Y Y d d 0 2 a0) 0 v '7 '7 a v v (n (6 CO co co CO n N. CO C) r c 2 a. 0 O , c m it .5. y d C N N c Yet- No. d .. .0 Of ..p N'o C ca, m U M o a 5 a ORIGINAL • • Ak.ulSk<1 c111 ,I (i ConocoPhillips (Alaska nc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad Plan: 1D-143 Plan: 1D-143L4 1 D-143L4wp12 Clearance Summary ailed,Anti-Collision Anticollision Report require 13 May,2014 Failed Anti-Collision for 1D-140, Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) 1D-140L1, 1 D-145 wp05 TCR required. Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L4-1D-143L4wp12 Well Coordinates: 5,959,120.00 N,1,700,702.00 E (70°17'57.34"N,149°30'42.30"W) Datum Height: Plan:70.7028 @ 98.70ft(Doyon 141) Scan Range: 0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build:69 Sca Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Sc n Type: 25.00 • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L4-1D-143L4wp12 Scan Range:0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft *Kuparuk 1D Pad 1D-141A-1D-141A-1D-141A(Projection) 1,302.69 264.30 1,302.69 235.78 1,350.00 9.268 Centre Distance Pass-Major Risk 1D-141A-1D-141A-1D-141A(Projection) 1,348.56 265.28 1,348.56 235.24 1,400.00 8.830 Clearance Factor Pass-Major Risk 1D-141A-1D-141A-1D-141A 1,302.69 264.30 1,302.69 235.54 1,350.00 9.191 Centre Distance Pass-Major Risk 1D-141A-1D-141A-1D-141A 1,348.56 265.28 1,348.56 235.00 1,400.00 8.760 Clearance Factor Pass-Major Risk Plan 1D-41-1D-41(Rig PROJ)-10-41 Intermediate S 706.27 283.08 706.27 270.49 725.00 22.477 Centre Distance Pass-Major Risk Plan 1D-41-1D-41(Rig PROJ)-1D-41 Intermediate S 999.88 285.06 999.88 267.01 1,025.00 15.794 Clearance Factor Pass-Major Risk Kuparuk 1C Pad 1C-127-1C-127-1C-127 8,810.34 1,078.16 8,810.34 841.77 5,800.00 4.561 Centre Distance Pass-Major Risk 1C-127-1C-127-1C-127 8,800.44 1,078.32 8,800.44 841.51 5,825.00 4.554 Clearance Factor Pass-Major Risk Kuparuk 1D Pad 1D-04-1D-04-1D-04 467.80 251.44 467.80 240.56 475.00 23.109 Centre Distance Pass-Major Risk 10-04-1D-04-1D-04 56243 252.47 562.43 239.28 575.00 19.135 Clearance Factor Pass-Major Risk 1D-04-1D-04A-1 D-04A 467.80 251.44 467.80 240.56 475.00 23.109 Centre Distance Pass-Major Risk 10-04-1D-04A-1D-04A 562.43 252.47 562.43 239.28 575.00 19.135 Clearance Factor Pass-Major Risk 10-04-1D-04AL1- 1D-04AL1 467.80 251.44 467.80 240.56 475.00 23.109 Centre Distance Pass-Major Risk 1D-04-1D-04AL1- 1D-04AL1 562.43 252.47 562.43 239.28 575.00 19.135 Clearance Factor Pass-Major Risk 1D-04-1D-04AL1-01-1D-04AL1-01 467.80 251.44 467.80 240.56 475.00 23.109 Centre Distance Pass-Major Risk 1D-04-1D-04AL1-01-1D-04AL1-01 562.43 252.47 562.43 239.28 575.00 19.135 Clearance Factor Pass-Major Risk 1D-04-1 D-04AL1-02-1 D-04AL1-02 467.80 251.44 467.80 240.56 475.00 23.109 Centre Distance Pass-Major Risk 1D-04-1 D-04AL1-02-1 D-04AL1-02 562.43 252.47 56243 23928 575.00 19.135 Clearance Factor Pass-Major Risk 1D-05-1D-05-1D-05 2,008.59 64.28 2,008,59 14.50 2,100.00 1.291 Centre Distance Pass-Major Risk 1D-05-1D-05-1D-05 2,029.99 64.77 2,029.99 14.34 2,125.00 1.284 Clearance Factor Pass-Major Risk 1D-06-1D-06-10-06 98.70 190.93 98.70 188.86 105.00 92.536 Centre Distance Pass-Major Risk 10-06-10-06-10-06 563.19 192.87 563.19 179.80 575.00 14.753 Clearance Factor Pass-Major Risk 1D-09-1D-09-1D-09 98.70 240.77 98.70 238.71 111.60 116.695 Centre Distance Pass-Major Risk 1D-09-10-09-10-09 624.83 244.15 624.83 233.58 650.00 23.105 Clearance Factor Pass-Major Risk 13 May,2014-14:43 Page 2 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup1 Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 1D Pad-Plan:ID-143-Plan:1D-143L4-1D-143L4wp12 Scan Range: 0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft 1D-102-1D-102-1D-102 2,551.87 242.58 2,551.87 184.61 2,800.00 4.185 Centre Distance Pass-Major Risk 1D-102-1D-102-1D-102 2,566.73 242.60 2,566.73 183.78 2,825.00 4.124 Clearance Factor • Pass-Major Risk 10-102-1D-102L1-1D-102L1 2,551.87 242.58 2,551.87 184.53 2,800.00 4.179 Centre Distance Pass-Major Risk 1D-102-1D-102L1-1D-102L1 2,566.73 242.60 2,566.73 183.70 2,825.00 4.119 Clearance Factor Pass-Major Risk 1D-102-1D-102PB1-1D-102PB1 2,551.87 242.58 2,551.87 184.54 2,800.00 4.180 Centre Distance Pass-Major Risk 1D-102-1D-102PB1-1D-102PB1 2,566.73 242.60 2,566.73 183.70 2,825.00 4.119 Clearance Factor Pass-Major Risk 10-102-1 D-102PB2-1 D-102PB2 2,551.87 242.58 2,551.87 184.53 2,800.00 4.179 Centre Distance Pass-Major Risk 1D-102-1 D-102PB2-1 D-102PB2 2,566.73 242.60 2,566.73 183.70 2,825.00 4.119 Clearance Factor Pass-Major Risk 10-102-1 D-102PB3-1 D-102PB3 2,551.87 242.58 2,551.87 184.53 2,800.00 4.179 Centre Distance Pass-Major Risk 10-102-1D-102PB3-1D-102PB3 2,566.73 242.60 2,566.73 183.70 2,825.00 4.119 Clearance Factor Pass-Major Risk 1 0-106-1D-106-1D-106 36.40 438.82 36.40 437.83 49.10 440.580 Centre Distance Pass-Major Risk 1 0-106-10-106-1 0-106 5,310.11 537.83 5,310.11 430.32 4,350.00 5.002 Clearance Factor Pass-Major Risk 1D-107-1D-107-1D-107 28.10 425.10 28.10 423.87 36.40 346.833 Centre Distance Pass-Major Risk 1D-107-1D-107-1D-107 649.61 427.55 649.61 415.39 675.00 35.155 Clearance Factor Pass-Major Risk 1D-118-1D-118-1D-118 412.30 261.11 412.30 254.15 425.00 37.496 Centre Distance Pass-Major Risk 1D-118-1D-118-1D-118 509.28 261.59 509.28 253.09 525.00 30.751 Clearance Factor Pass-Major Risk 1D-119-1D-119-1D-119 461.58 228.91 461.58 220.82 475.00 28.320 Centre Distance Pass-Major Risk 1D-119-1D-119-1D-119 509.26 229.31 509.26 220.46 525.00 25.915 Clearance Factor Pass-Major Risk 10-120-1D-120-1D-120 2,974.16 133.46 2,974.16 79.69 3,000.00 2.482 Clearance Factor Pass-Major Risk 10-120-10-120-10-120 2,995.95 133.26 2,995.95 80.29 3,025.00 2.516 Centre Distance Pass-Major Risk 10-121-1D-121-1D-121 98.70 213.30 98.70 211.24 112.00 103.380 Centre Distance Pass-Major Risk 1D-121-10-121-1D-121 484.97 214.83 484.97 206.39 500.00 25.443 Clearance Factor Pass-Major Risk 1D-122-10-122-10-122 61.60 205.59 61.60 203.90 75.00 121.639 Centre Distance Pass-Major Risk 1D-122-1 D-122-1D-122 336.58 207.52 336.58 201.21 350.00 32.858 Clearance Factor Pass-Major Risk 1D-123-1D-123-1D-123 236.59 197.61 236.59 193.29 250.00 45.738 Centre Distance Pass-Major Risk 10-123-1D-123-1D-123 286.58 198.07 286.58 192.92 300.00 38.457 Clearance Factor Pass-Major Risk 1D-124-1D-124-1D-124 461.81 179.81 461.81 171.75 475.00 22,300 Centre Distance Pass-Major Risk 10-124-1D-124-1D-124 509.56 180.30 509.56 171.49 525.00 20.464 Clearance Factor Pass-Major Risk 1D-125-1D-125-1D-125 86.90 179.79 86.90 177.68 100.00 84.917 Centre Distance Pass-Major Risk 1D-125-1D-125-1D-125 461.34 180.71 461.34 172.50 475.00 22.012 Clearance Factor Pass-Major Risk 13 May,2014- 14:43 Page 3 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 10-143 - 1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L4-1D-143L4wp12 Scan Range: 0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft 1D-125-1D-125A-1D-125A 98.45 179.79 98.45 177.63 100.00 83.174 Centre Distance Pass-Major Risk 1D-125-1D-125A-1D-125A 472.37 180.93 472.37 172.65 475.00 21.865 Clearance Factor Pass-Major Risk 1D-126-1D-126-1D-126 98.70 179.43 98.70 177.26 111.30 82.587 Centre Distance Pass-Major Risk 1 D-126-1 D-126-1 D-126 237.39 180.02 237.39 175.90 250.00 43.779 Clearance Factor Pass-Major Risk 1D-126-Plan:1 D-126A-1 D-126A(wp02) 98.70 179.43 98.70 177.26 111.30 82.587 Centre Distance Pass-Major Risk 1D-126-Plan:1D-126A-1D-126A(wp02) 237.39 180.02 237.39 175.77 250.00 42.436 Clearance Factor Pass-Major Risk 1D-127-1D-127-1D-127 86.90 180.45 86.90 178.33 100.00 85.226 Centre Distance Pass-Major Risk 1D-127-1D-127-1D-127 186.89 181.20 186.89 177.83 200.00 53.680 Clearance Factor Pass-Major Risk 1D-128-1D-128-1D-128 98.70 182.74 98.70 180.67 111.80 88.565 Centre Distance Pass-Major Risk 1 D-128-1D-128-1D-128 461.36 184.48 461.36 176.45 475.00 22.972 Clearance Factor Pass-Major Risk 1D-129-1D-129-1D-129 212.20 202.24 212.20 198.31 225.00 51.469 Centre Distance Pass-Major Risk 1D-129-1D-129-1D-129 262.19 202.74 262.19 197.99 275.00 42.665 Clearance Factor Pass-Major Risk 1D-130-1D-130-1D-130 461.68 208.92 461.68 200.89 475.00 26.002 Centre Distance Pass-Major Risk 1D-130-10.130-1D-130 533.50 209.39 533.50 200.26 550.00 22.925 Clearance Factor Pass-Major Risk 1D-131-1D-131-1D-131 98.70 218.28 98.70 216.21 112.00 105.791 Centre Distance Pass-Major Risk 1D-131-1D-131-1D-131 186.70 218.90 186.70 215.39 200.00 62.366 Clearance Factor Pass-Major Risk 1D-133-1D-133-1D-133 237.17 236.56 237.17 232.22 250.00 54.462 Centre Distance Pass-Major Risk 1 D-133-1D-133-1D-133 461.63 238.03 461.63 230.02 475.00 29.694 Clearance Factor Pass-Major Risk 1D-133-1 D-133PB1-1D-133PB1 237.17 236.56 237.17 232.22 250.00 54.462 Centre Distance Pass-Major Risk 1D-133-1 D-133PB1-1 D-133PB1 461.63 238.03 461.63 230.02 475.00 29.694 Clearance Factor Pass-Major Risk 1D-135-1D-135-1D-135 1,767.29 246.50 1,767.29 210.60 1,825.00 6.865 Centre Distance Pass-Major Risk 1D-135-1D-135-1D-135 1,813.49 247.39 1,813.49 209.95 1,875.00 6.607 Clearance Factor Pass-Major Risk 1D-140-1D-140-1D-140 _ 111111111 111111111 ® IIIIMBEIT 1D-140-1D-140-1D-140 MINIM III.IIMI ® I.17,975.00 0.606 Clearance Factor FAIL-Major Risk 1D-140-1D-140L1-1D-140 L1 - ® - - ®6,700.00 0.571 Centre Distance FAIL-Major Risk 1D-140-1D-140L1-1D-140 L1 ® ® ® ® NMI= rialsasiaa figtftitiatlaMbritataa.ile--Major I! 1D-140-1 D-140PB1-1D-140PB1 5,583.10 159.15 5,583.10 15.51 5,325.00 1.108 Centre Distance Pass-Major Risk 1D-140-1 D-140PB1-1D-140PB1 6,080.98 171.27 6,080.98 3.33 5,825.00 1.020 Clearance Factor Pass-Major Risk 1D-141-1D-141-1D-141 1,578.90 198.97 1,578.90 159.34 1,675.00 5.021 Centre Distance Pass-Major Risk 1D-141-1D-141-1D-141 1,599.84 199.66 1,599.84 159.15 1,700.00 4.929 Clearance Factor Pass-Major Risk 13 May,2014- 14:43 Page 4 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L4-1D-143L4wp12 Scan Range:0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft 1D-141-1D-141A-1D-141A 1,570.08 198.94 1,570.08 159.37 1,675.00 5.027 Centre Distance Pass-Major Risk 1 D-141-1D-141A-1D-141A 1,591.12 199.26 1,591.12 158.77 1,700.00 4.921 Clearance Factor Pass-Major Risk 1D-141-1D-141APB1-1D-141APB1 1,570.08 198.94 1,570.08 159.61 1,675.00 5.058 Centre Distance Pass-Major Risk 1D-141-1D-141APB1-1D-141AP81 1,591.12 199.26 1,591.12 159.01 1,700.00 4.950 Clearance Factor Pass-Major Risk 1 D-141-1 D-141APB2-1 D-141AP82 1,570.08 198.94 1,570.08 159.61 1,675.00 5.058 Centre Distance Pass-Major Risk 1D-141-1D-141APB2-1D-141AP82 1,591.12 199.26 1,591.12 159.01 1,700.00 4.950 Clearance Factor Pass-Major Risk 1D-141-1D-141APB3-1D-141APB3 1,570.08 198.94 1,570.08 159.61 1,675.00 5.058 Centre Distance Pass-Major Risk 1D-141-1D-141AP83-1D-141APB3 1,591.12 199.26 1,591.12 159.01 1,700.00 4.950 Clearance Factor Pass-Major Risk 1D-141-1D-141L1-1D-t41 L1 1,578.90 198.97 1,578.90 159.34 1,675.00 5.021 Centre Distance Pass-Major Risk 1D-141-1D-141L1-1D-141L1 1,599.84 199.66 1,599.84 159.15 1,700.00 4.929 Clearance Factor Pass-Major Risk 1D-141-1D-141L1PB1-1D-141L1PB1 1,578.90 198.97 1,578.90 159.34 1,675.00 5.021 Centre Distance Pass-Major Risk 1D-141-1D-141 L1 PB1-1D-141 L1 PB1 1,599.84 199.66 1,599.84 159.15 1,700.00 4.929 Clearance Factor Pass-Major Risk 1 D-141-1 D-141 L1 PB2-1 D-141 L1 PB2 1,578.90 198.97 1,578.90 159.34 1,675.00 5.021 Centre Distance Pass-Major Risk 1D-141-1D-141 L1 PB2-tD-14tL1 PB2 1,599.84 199.66 1,599.84 159.15 1,700.00 4.929 Clearance Factor Pass-Major Risk 1D-141-1D-141PB1-1D-141PB1 1,578.90 198.97 1,578.90 159.10 1,675.00 4.991 Centre Distance Pass-Major Risk 1D-141-1 D-141 PB1-1D-141PB1 1,599.84 199.66 1,599.84 158.91 1,700.00 4.900 Clearance Factor Pass-Major Risk 1 D-28-1D-28-1D-28 518.01 53.75 518.01 44.69 525.00 5.931 Centre Distance Pass-Major Risk 1D-28-1D-28-1D-28 618.11 54.49 618.11 43.97 ' 625.00 5.181 Clearance Factor Pass-Major Risk tD-28-1D-28L1-1D-28L1 518.01 53.75 518.01 44.69 525.00 5.931 Centre Distance Pass-Major Risk 1D-28-1D-28L1-1D-28L1 618.11 54.49 618.11 43.97 625.00 5.181 Clearance Factor Pass-Major Risk 1D-30-1D-30-1D-30 1,172.03 71.04 1,172.03 51.67 1,175.00 3.667 Centre Distance Pass-Major Risk 1D-30-1D-30-1D-30 1,196.69 71.35 1,196.69 51.62 1,200.00 3.616 Clearance Factor Pass-Major Risk 1D-30-1D-30L1-1D-30L1 1,172.03 71.04 1,172.03- 51.66 1,175.00 3.665 Centre Distance Pass-Major Risk 1D-30-1D-30L1-1D-30L1 1,196.69 71.35 1,196.69 51.61 1,200.00 3.614 Clearance Factor Pass-Major Risk 1D-32-1D-32-1D-32 902.84 116.12 902.84 100.65 900.00 7.504 Centre Distance Pass-Major Risk 1D-32-1D-32-1D-32 952.40 116.65 952.40 100.26 950.00 7.115 Clearance Factor Pass-Major Risk 1D-32-1D-32L1-1D-32L1 902.84 116.12 902.84 100.87 900.00 7.614 Centre Distance Pass-Major Risk 1D-32-1D-32L1-1D-32L1 952.40 116.65 952.40 100.48 950.00 7.213 Clearance Factor Pass-Major Risk 1D-32-1D-32L1PB1-1D-32LtPB1 902.84 116.12 902.84 100.63 900.00 7.498 Centre Distance Pass-Major Risk 1D-32-1D-32L1PB1-1D-32L1PB1 952.40 116.65 952.40 100.24 950.00 7.109 Clearance Factor Pass-Major Risk 13 May,2014- 14:43 Page 5 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:ID-143-Plan:1D-143L4-1D-143L4wp12 Scan Range:0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft 1D-34-1D-34-1D-34 468.63 148.49 468.63 140.24 475.00 17.997 Centre Distance Pass-Major Risk 1D-34-1D-34-1D-34 543.81 149.06 543.81 139.63 550,00 15.814 Clearance Factor Pass-Major Risk 1D-34-1D-34L1-1D-34L1 467.62 148.49 467.62 140.25 475.00 18.031 Centre Distance Pass-Major Risk 1D-34-1D-34L1-1D-34L1 542.81 149.04 542.81 139.63 550.00 15.837 Clearance Factor Pass-Major Risk 1D-34-1D-34L1P B1-1D-34L1PB1 467.62 148.49 467.62 140.25 475.00 18.031 Centre Distance Pass-Major Risk 1D-34-1D-34L1PB1-1D-34L1PB1 542.81 149.04 542.81 139.63 550.00 15.837 Clearance Factor Pass-Major Risk 1D-36-1D-36-1 D-36 243.40 179.22 243.40 174.80 250.00 40.571 Centre Distance Pass-Major Risk 1D-36-1D-36-1D-36 878.83 185.46 878.83 170.29 875.00 12.225 Clearance Factor Pass-Major Risk 1D-36-10-36-1D-36WP4(Baker) 318.40 179.58 318.40 173.92 325.00 31.751 Centre Distance Pass-Major Risk 1D-36-10-36-1D-36WP4(Baker) 903.95 183.24 903.95 167.57 900.00 11.697 Clearance Factor Pass-Major Risk 10-36-1D-36L1-1D-36L1 242.70 179.22 242.70 174.81 250.00 40.676 Centre Distance Pass-Major Risk 1D-36-1D-36L1-1D-36L1 878.10 185.45 878.10 170.28 875.00 12.225 Clearance Factor Pass-Major Risk 10-36-1D-36L2-1D-36L2 242.70 179.22 242.70 174.81 250.00 40.676 Centre Distance Pass-Major Risk 1 D-36-1D-36L2-1D-36L2 878.10 185.45 878.10 170.28 875.00 12.225 Clearance Factor Pass-Major Risk 1D-37-1D-37-1D-37 819.23 187.18 819.23 173.71 825.00 13.894 Centre Distance Pass-Major Risk 1D-37-1D-37-1D-37 892.58 188.02 892.58 173.39 900.00 12.847 Clearance Factor Pass-Major Risk 1D-37-1D-37L1-1D-37L1 818.15 187.18 818.15 173.72 825.00 13.912 Centre Distance Pass-Major Risk 1D-37-1D-37L1-1D-37L1 891.51 188.01 891.51 173.39 900.00 12.861 Clearance Factor Pass-Major Risk 1D-37-1D-37L2-1D-37L2 818.15 187.18 818.15 173.72 825.00 13.912 Centre Distance Pass-Major Risk 1D-37-1D-37L2-1D-37L2 891.51 188.01 891.51 173.39 900.00 12.861 Clearance Factor Pass-Major Risk 1D-37-1D-37L2PB1-1 D-37L2PB1 818.15 187.18 818.15 173.72 825.00 13.912 Centre Distance Pass-Major Risk 1D-37-1D-37L2PB1-1D-37L2PB1 891.51 188.01 891.51 173.39 900.00 12.861 Clearance Factor Pass-Major Risk 1D-38-1D-38-1D-38 1,542.14 184.45 1,542.14 160.19 1,550.00 7.601 Centre Distance Pass-Major Risk 1D-38-1D-38-1D-38 1,641.61 185.32 1,641.61 159.45 1,650.00 7.162 Clearance Factor Pass-Major Risk 1D-39-1D-39-1D-39 965.79 218.85 965.79 202.84 1,075.00 13.667 Centre Distance Pass-Major Risk 1D-39-1D-39-1D-39 1,039.82 219.26 1,039.82 202.15 1,150.00 12.814 Clearance Factor Pass-Major Risk 1D-40-1D-40-1D-40 902.00 232.81 902,00 217.94 900.00 15.655 Centre Distance Pass-Major Risk 1D-40-1D-40-1D-40 951.51 233.37 951.51 217.68 950.00 14.877 Clearance Factor Pass-Major Risk 10-40-1 D-40A-1 D-40A 902.84 232.81 902.84 217.93 900.00 15.641 Centre Distance Pass-Major Risk 10-40-1D-40A-1D-40A 952.36 233.38 952.36 217.68 950.00 14.865 Clearance Factor Pass-Major Risk 13 May,2014- 14:43 Page 6 of 10 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1D-143-1 D-143L4wp12 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1D Pad-Plan:1D-143-Plan:1D-143L4-1D-143L4wp12 Scan Range:0.00 to 9,090.13 ft.Measured Depth. Scan Radius is 1,106.21 ft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft 1D-41-1D-41-1D-41 112.80 254.03 112.80 251.52 125.00 100.874 Centre Distance Pass-Major Risk 1 D-41-1D-41-1 D-41 212.79 254.72 212.79 250.24 225.00 56.886 Clearance Factor Pass-Major Risk 1D-41-1 D-41 PB1-1 D-41 PB1 112.80 254.03 112.80 251.41 125.00 96.675 Centre Distance Pass-Major Risk 1D-41-1D-41PB1-1 D-41 PB1 212.79 254.72 212.79 250.13 225.00 55.529 Clearance Factor Pass-Major Risk 1D-42-1D-42-1D-42(Baker) 1,075.78 259.89 1,075.78 242.23 1,075.00 14.713 Centre Distance Pass-Major Risk 1D-42-1D-42-1D-42(Baker) 1,100.23 259.97 1,100.23 241.95 1,100.00 14.423 Clearance Factor Pass-Major Risk 1D-42-1D-42-1D-42 976.69 266.67 976.69 250.53 975.00 16.522 Centre Distance Pass-Major Risk 1D 42-1D 42-1D 42 1,001.20 266.89 1,001.20 250.34 1,000.00 16.132 Clearance Factor Pass-Major Risk 1D-42-1D-42L1-1D-42L1 975.71 266.67 975.71 250.88 975.00 16.882 Centre Distance Pass-Major Risk 1 D-42-1D-42L1-1D-42L1 1,000.22 266.87 1,000.22 250.67 1,000.00 16.472 Clearance Factor Pass-Major Risk 1D-42-1D-42L1PB1-1D-42L1PB1 975.71 266.67 975.71 250.55 975.00 16.539 Centre Distance Pass-Major Risk 1D-42-1D-42L1 PB1-1D-42L1PB1 1,000.22 266.87 1,000.22 250.34 1,000.00 16.145 Clearance Factor Pass-Major Risk Plan:1D-142-Plan 1D-142-1D-142wp04 450.00 30.00 450.00 21.78 450.00 3.651 Centre Distance Pass-Major Risk Plan:1 D-142-Plan 1D-142-1D-142wp04 624.50 30.90 624.50 19.88 625.00 2.803 Clearance Factor Pass-Major Risk Plan:1D-143-Plan:1D-143-1D-143wp11 ® ® MEM ® MEM - - Plan:1D-143-Plan:1D-143L1-1D-143L1wp11 ® ® IIIIIME ® - Plan:1 D-143-Plan:1 D-143L2-1 D-143L2wp11 ® ® ® MIME MIEIIIEI ® - Plan:1D-145-Plan:1D-145-1D-145wp03 ® ® ® ® ® ® Millegall= I',AII, ,,ii,,'.,:1':: Plan:1D-145-Plan:10-145-1D-145wp03 ® ® ® ® ® ® MiliElli'::\II t.:1.P;ilii:' Survey tool program From To Survey/Plan Survey Tool (ft) (ft) 28.00 1,000.00 GYD-GC-SS 1,000.00 4,309.00 MWD+IFR-AK-CAZ-SC 4,309.00 9,090.13 1D-143L4wp12 MWD+IFR-AK-CAZ-SC 13 May,2014- 14:43 Page 7 of 10 COMPASS Sec Inc Azl TVD +N/-S +E/-W DLeg TFace VSec Tar. 1 4 76.56 352.80 3661.59 1154.84 238.96 0.00 0.00 1154.84 1 D-143 L 3w p 12.1 2 4 78.80 352.80 3665.11 1170.83 13.56 0.00 1170.83 3 4355.50 78.80 352.80 3670.94 1200.03 233.25 10 00 0.00 1200.03 0 4180 4 4584.56 90.00 352.80 3693.26 1425.84 204.73 4.89 -0.01 1425.84 4309.00 To 9090.13 54614.56 90.00 352.80 369326 1455.61 200.97 0.00 0.00 1455.61 4180 4300 64653.74 91.17 352.71 3692.86 1494.46 196.03 3.00 -4.25 1494.46 7 5617.22 91.17 352.71 3673.15 2449.96 73.85 0.00 0.00 2449.96 4300 4400 8 5777.10 87.00 355.08 3675.70 2608.87 56.86 3.00 150.44 2608.87 1D-143 D-Lat MW 02May14 CP1 S_flt 11'06,September 19 2014 95888.99 83.64 355.09 3684.83 2719.96 47.30 3.00 179.90 2719.96 4400 4500 • 10 6036.25 83.64 355.09 3701.13 2865.78 34.76 0.00 0.00 2865.78 11 6273.58 89.80 358.67 3714.70 3102.22 21.89 3.00 30.29 3102.22 1D-143 D-Lal MW 29Jan14 CP2 N_flt 4500 4600 12 6287.79 90.08 358.67 3714.71 3116.42 21.56 2.00 -0.53 3116.42 13 7773.28 90.08 358.67 3712.54 4601.51 -12.99 0.00 L )BAL FILTER APPLIED: Al 4601.51 147808.48 89.38 358.67 3712.70 4636.70 -13.81 2.00 179.7974636.70 10-143 0-Lat MW 29Jan14 CP3 4600 4700 15 8749.74 89.38 17.50 3723.00 5564.37 117.94 2.00 90.11 5564.37 16 9090.13 89.38 17.50 3726.70 5888.99 220.27 0.00 0.00 5888.99 1D-143 D-Lat MW 29Jan14 CP4 TD DB 4700 4800 ap 6 From O..To Survey., Tool 4800 4900 26.00 1000.00 10-143.213.1(P1nn:16143) 0366355 1000.00 2369.47 10-143.212.1 Mon:16143) 14W2.1F64.6p2-SC 4900 5200 2369.47 4309.00 10-143w012.1(Plan)16143) 065C 4309.00 4600.00 161431.3.212.1(Plan)161431.3)1146,11.413TP6N0 4600.00 6100.00 1614363.212.1(Plan)161431.3)MWD 5200 5400 4600.00 9090.13 161431.3.212.1(Plan:161431.3)202/13+1F64126265C 5400 5700 CASING DETAILS 5700 6000 ND MD Name Size 6000 6200 2343.70 2369.47 13-3/8"x16" 13-3/8 3693.26 4584.56 9-5/8"x 12-1/4" 9-5/8 6200 6500 3726.70 9090.13 4-1/2"x 6-3/4" 4-1/2 6500 6700 0/360 6700 7000 75 7000 7300 -30/330 70 -_-� 30 7300 7500 i-------- 7500 7800 60 7800 8000 /j V 8000 8300 50 8300 8500 // 45 8500 8800 60/300 \ 40 :, : � 60 8800 9060 3 /11A.1 350 \, 25 .,, 4/(1 i1i , lif I It 0 04 To -90/270 90 jiil ;i \'\N Aultiff. z'' ////'/' # 71' 4.+ N' _ ; 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'i 60 fi a -mtwitot-\ ,,,,;,,,,,,,---.,-,-4,1,,,,,,,,,- _gam', y��� _ �'� o -90/270 ��� � , N ���, �. ���; � � \' ''' -90 �„ / I. t }:•8111 7 \ VI.::',, .V-I • .,„ ..--,s;i54-,- , 'N\l`t;tki\N‘4Y. !k, \tr,,,Itikt,,I,,f-*A\''\1;''''' //' ' 1/1, ' ' \$ 1 A0 V 1L*41/4.4?�''‘I''''''''' �f,r ` e +r 1♦ iA r , \„.,,,,,•,.., \/�{ �/i � �! � � f/Jiei lq`'4p���I«7 f l � l6 1t' • 11 [_1 1.,� �1II �� 1A \f,, Al' 101,1.O�^44'itt ififiA i � 1I X11,11i t.,RGe 1,1 1 i t 4 � - 3 V ��i5143�i 1 , i'.I ,vj -'r 111 -�� -120/240 �am 3�,.. _ a � o � � '� c 101 r, y, • � �, ',is A,"4,, ' 1��2 i +y�, s \ 1 r "11 'a '.;�{ /\ / "4 / -.,/ , 150-150/210 y i_ wP -180/180 0 R i kJ ' 12 ' af,',...n...- 2.1,10 124,1D 12.2 441„ 120 O , P9,y4 • i Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Tuesday, October 28, 2014 9:20 AM To: Loepp,Victoria T (DOA) Subject: RE: KRU 1D-143L1(PTD 214-146); KRU 1D-143L3(PTD 214-148) Anti-collision analysis Attachments: 1D-143L3wp13ACSummary.pdf; 1D-143L1wp13ACSummary.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, here are the updated AC's with the error fixed so it does not show those wells as failing. I will call to follow up. David From: Loepp, Victoria T(DOA) [mailto:victoria.loeppCa alaska.gov] Sent: Friday, October 24, 2014 9:14 AM To: Lee, David L Subject: [EXTERNAL]KRU 1D-143L1(PTD 214-146); KRU 1D-143L3(PTD 214-148) Anti-collision analysis David, Have you had a chance to get revised anti-collision summary reports with the modifications we talked about for those wells showing major risk failures? I would like to get your PTDs processed as soon as you have this information. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALRY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 • • Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 22, 2014 10:34 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1D-143L1(PTD 214-146); KRU 1D-143L3(PTD 214-148)Anti-collision analysis Follow Up Flag: Follow up Flag Status: Flagged Morning Victoria,the wells that we failed major risk were: 1C-109 (laterals in B and D)—TCR has been completed,will mitigate by: When we drill the lowest lateral (1D-143),and L2 lateral we will be using periscope so leaving risk of leaving zone is minimal,and since 1C-109 has laterals in the B and D sands, if we don't leave zone we will not hit the well. 1D-140 (laterals in B and D) )—TCR has been completed,will mitigate by: When we drill the lowest lateral (1D-143), L1 and L2 laterals we will be using periscope so leaving risk of leaving zone is minimal, and since 1D-140 has laterals in the B and D sands, if we don't leave zone we will not hit the well. For the L3 lateral,when drilled we will closely monitor for magnetic interference, and if interference is picked up we will drill away from the well. 1D-140 is currently shut in and suspended, so if we did hit it while drilling there is no environmental or safety risk. 1D-143 (Colliding laterals with themselves)—All laterals will be drilled using periscope so risk of leaving zone is minimal eliminating the collision risk. 10-145 (planned well)—1D-145 is a planned well to be drilled after 10-143, 1D-143 will be drilled using periscope and 1D-145 lateral is going to be in the B sand, so risk of crossing planned line is minimal. If we did cross the planned line 10-145 would just have to be re planned. If you have further questions or any concerns please let me know. David From: Loepp, Victoria T(DOA) [mailto;victoria.loepp@alaska.gov] Sent: Tuesday, October 21, 2014 4:33 PM To: Lee, David L Subject: [EXTERNAL]KRU 1D-143L1(PTD 214-146); KRU 1D-143L3(PTD 214-148) Anti-collision analysis David, 1. Anti-collision analysis 1D-143L1: 1D-01, 10-101, 10-108. 10-107 fail major risk:What steps will be taken with these wells to mitigate risk of collision during drilling 1D-143L1? Did I miss the TCRs or explanation? 2. Anti-collision analysis 1D-143L3: 1C-127, 10-01, 1D-09, 10-101, 1D-106, 10-107, 1D-118, 10-14 fail major risk: What steps will be taken with these wells to mitigate risk of collision during drilling 1D-143L13? Did I miss the TCRs or explanation? Thanx, Victoria Victoria Loepp 1 Bettis, Patricia K (DOA) ?i 0/1-I�� From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 01, 2014 4:20 PM To: Bettis, Patricia K (DOA) Cc: Jolley, Liz C; Hallford, Kelsey Subject: 1D Permits to Drill Attachments: Permit to Drill 1D-142.pdf; 1D-142wp06 -Plan Summary.pdf; Permit to Drill 1D-143 Ll.pdf; Permit to Drill 1D-143 L2.pdf; Permit to Drill 1D-143 L3.pdf; Permit to Drill 1D-143.pdf; 1D-143L1wp13 PlanSummary.pdf; 1D-143L2wp13 PlanSummary.pdf; 1D-143L3wp13 PlanSummary.pdf; 1D-143wp13 PlanSummary.pdf; Permit to Drill 1D-145.pdf; 1D-145wp06- Plan Summary.pdf; Permit to Drill 1D-146.pdf; 1D-146wp04- Plan Summary.pdf Patricia, as we discussed on the phone,the 1D wells ended up having their surface locations shifted by^'17'. Attached please find the updated 10-401's for each of the wells as well as the updated directional plans with the new surface coordinates. If you have any questions or require any further information please let me know. Thanks David 1 • • Bettis, Patricia K (DOA) y IY kc From: Lee, David L <David.L.Lee@conocophillips.com> i��� I� -SL./3 4,3 Sent: Friday, September 19, 2014 11:22 AM To: Bettis, Patricia K (DOA) Cc: Ferguson, Victoria L (DOA) Subject: RE: Naming Convention for Lateral Wells Attachments: 1D-143L3wp12.1 -Plan Summary.pdf Thanks for the clarity Patricia. Can we rename the wells to be: 1D-143 (A2)—Renamed to 1D-143 1D-143 (A3)—Renamed to 1D-143L1 1D-143 (A4)—Renamed to 1D-143L2 X143 (D1=Renamed to 1D-143L3 I have re--atttaached the 1D-143(D), now 1D-143L3 well plan with its new name (it has 1D-143L4 in its name currently). If you need anything else please let me know. Thanks David Lee From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, September 18, 2014 5:46 PM To: Lee, David L Cc: Ferguson, Victoria L (DOA) Subject: [EXTERNAL]Naming Convention for Lateral Wells Good afternoon David, Just received the permit to drill applications for 1D-143(A3), 1D-143(A2), 1D-143(A4), 1D-143(D). AOGCC issues a separate permit to drill for every wellbore because we wish to track exactly where each wellbore is located (to avoid collisions) and what sort of pipe, cement and jewelry are in the wellbore(s). . Around 2005,operators here in Alaska began to drill more complex wells. For example, a well named Kuparuk River Unit 1E-08 (50-029-20496- 00-00)was plugged and abandoned, a whipstock was set, and the well was redrilled (sidetracked)to a new bottom hole location. This new well was named Kuparuk River Unit 1E-08A and its API number became 50-029-20496-01-00. The next year, the operator decided to leave this sidetrack open to the formation and to add two horizontal lateral wellbores that branch from the sidetrack well 1E-08A. These horizontal lateral wellbores are named Kuparuk River Unit 1E-08AL1 and Kuparuk River Unit 1E-08AL2, respectively. From these two lateral wellbores, the operator subsequently decided to drill three additional wellbores, which AOGCC terms"spokes." The resulting names and API numbers below are presented in the order these wellbores were permitted and drilled. Kuparuk River Unit 1E-08 50-029-20496-00-00 Plugged and abandoned original wellbore Kuparuk River Unit 1E-08A 50-029-20496-01-00 Sidetrack of original wellbore, left open to the formation to continue production 1 • } • • Kuparuk River Unit 1E-08AL1 50-029-20496-60-00 First lateral wellbore drilled from the sidetrack of the original wellbore to the same reservoir Kuparuk River Unit 1E-08AL1-01 50-029-20496-61-00 First spoke wellbore drilled from the first lateral wellbore to the same reservoir Kuparuk River Unit 1E-08AL1-02 50-029-20496-62-00 Second spoke drilled from the first lateral wellbore to the same reservoir Kuparuk River Unit 1E-08AL2 50-029-20496-63-00 Second lateral drilled from the sidetrack of the original wellbore to the same reservoir Kuparuk River Unit 1E-08AL2-01 50-029-20496-64-00 First spoke drilled from the second lateral wellbore to the same reservoir Kuparuk River Unit 1E-08AL1-03 50-029-20496-65-00 Third spoke drilled from the first lateral wellbore to the same reservoir This particular well currently has the main wellbore (1E-08A)and six subsidiary horizontal wellbores open to the reservoir and contributing to production. Based on this well naming scheme, one can immediately get a sense of which spoke wellbores branch from which lateral wellbores. If ConocoPhillips decided to plug and abandon the 1E-08A and all of its laterals and redrill the well,the new well would be named 1E-08B ("B" for sidetrack or redrill#2). The first lateral off of 1E-08B would be named 1E-08BL1 and so forth. To illustrate this well naming convention further, I have attached the API Naming Convention and schematic. Please review the proposed wells 1D-143(D), 1D-143(A2), 1D-143(A4), and 1D-143(A3), and rename these wells in accordance to the well naming convention. (You can advise me of the revised well names by e-mail). If you want internally to call a well 1D-143L1 (D) and 1D-143L1-01(A2),that would be fine. However,the AOGCC would leave the "(D)" and "(A2)" off of its records. Please give me a call, if you would like to discuss this further. Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) 13176 Qt'/-I'i' From: Lee, David L <David.L.Lee@conocophillips.com> IkRA. It— /9347) Sent: Thursday, September 18, 2014 2:20 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 1D-145: Permit to Drill Application Morning Patricia, here are the logging program for each of the 1D Wells: 1D-142 Surface—Gamma, Resistivity, Density, Neutron Intermediate—Gamma, Resistivity Lateral—Gamma, Resistivity, sonic (for cement top evaluation) and periscope 1D-143 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, density, neutron Lateral x 4—Gamma, Resistivity and periscope 1D-146 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity Lateral x 4—Gamma, Resistivity and periscope 1D-145 Surface—Gamma, Resistivity Intermediate—Gamma, Resistivity, Lateral x 4—Gamma, Resistivity and periscope Please let me know if you need anything else. Thanks David From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, September 18, 2014 9:12 AM To: Lee, David L Subject: [EXTERNAL]KRU 1D-145: Permit to Drill Application Good morning David, Please submit the logging program for each section of the proposed well. Thank you, Patricia 1 • . Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 0211/ ` Ik0 Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: 144. QW W". �\/ fl POOL: Ky& 1J/E.J' tdiS &kik Oil Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit V (If last two digits No. a III- "195 , API No. 50- OM ,235 -00 - 00 . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 • • 11 El T o aa) a CON a) o N o@ a ) a m' d F' { ,_ *_E� , co co 0 0' 7 c c 0 co co cas `o z o ca d w cn P. 'o w' aS O 0 LU O C 3 a c E O a° o o n 3' a) co, E. > 0 � of a) a o ca) 3 0-'. U = 0 O : >, .. O. _ m o U) a a) U a q 3 ami o Q o c 3 ._ • rn co J D a) d g u) 0. o. CO O �, c. a)' N. 0 u) T, W. .N N C, d CS CD c U O @ L N. �' O O NO V. O i N. E. '3. > V� U)� N. -0 F O J •i a. E.. U• a� D: : 0 6)� co _� C, JCO - c CO LOa', 0' E. a; a)'0 0 co F = _ a �, �' m �' a 3 @' y' w '3 0, ac) Y ° c w e c u) 3 7. Z s a a t -@0, 4 E m L0 D 0 0 E 0 0 ass 0 > 0 'y m0 - v, 112 OO. O O. 7. 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