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206-042
RECEIVED • • MAY11 ?_011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANt9Q,0 la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned i Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 31yy'1'fi 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/20/2017 a. 206-042/317-035/ ' 3.Address: 7. Date Spudded: t,L- 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 3/C/2006 3'Zt I zoe(, 50-103-20526-60 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1334'FSL,874'FEL,Sec 5,T12N, R5E, UM 3/22/2006 CROD3-111 L1 Top of Productive Interval: 9. Ref Elevations: KB.Wg6 r" 17. Field/Pool(s): CI V F 0rJ i/ 188'FSL, 173'FEL,Sec 31,T13N, R5E,UM GL: )7.1 BF: Fie r+n���pariik Oil-P Cf�J�(� Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: / 7 1515'FSL,487'FWL,Sec 30,T13N,R5E, UM 2521/2301 ADL 372105,ADL 364471,ADL 36447( ' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- SeSt(c°I y- (0603$Zg Zone- 4 16645/6857 LAS21122 TPI: x- 386283 y- 6007991 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 381770 y- 6014669 Zone- 4 2130/1994 1270/1244 5. Directional or Inclination Survey: Yes ❑ (attached) No E 13.Water Depth, if Offshore: 21. Re-drill/Lateral To Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 11-k;°0. /6,(6111' 4.-- 22. v22.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 N/A SCANNED JUN 0 92012, 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 16 84 J-55 36.6 114 36.6 114 24 10 cu yds Portland Type III 9 5/8 40 L-80 36.6 2721 36.6 2469 12.25 410 sx Class G,230 sx Class G 7 26 L-80 36.6 8660 36.6 6932 8.75 190 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 8160 8101 OPEN HOLE PLUGGED BACK @ 2521 MD and 2303 ND AgAN 0 0 wet) A,,, ; ;: . 41-, 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. /2 .1/1-'4-/+ri- Was hydraulic fracturing used during completion? Yes❑ No ❑ 2Per 20 AAC 25.283(i)(2)attach electronic and printed information ratriE_ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lk-- Plug Back Cement @ 2521 43.4 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - pi. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 11/2015 v y'i. G ��7' CONTINUED ON PAGE 2 RBDMS Lt- MAY 1 5 2017 Submit ORIGINIAL o ly/� 1143 4/WO � 0777 l� • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1270 1244 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Cement Report,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marshall Brown(a)Ia. _265-6218 Email: H.Marshall.BrownCa�conocophillips.com l 1 We) Printed Na .T.S:`den Title: Well Integrity Intervention Director G Signature:' `,A\�� \ Phone: 265-1544 Date: �! 17 INSTRUCTIONS / / General: This form and required required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-40 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 1a: 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,Ground Level,and Base Flange 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 11/2015 Submit ORIGINAL Only • • CD3-111L1 DTTMST JOBTYF SUMMARYOPS 3/11/17 DRILLA`Move and stage rig support modules @ CD2 ice pad, move Sub structure 13.9 miles up to CD2 ice road ramp(Mile 15.9). Support mod maintenance, Prep well CD3-111A, lay rig mats @ Tamayayak bridge. Notify AOGCC of upcoming test. 3/12/17 DRILLIN Continue moving Sub to CD3, spot/center sub over well. SIMOPS- Move support modules to CD3. Make up pit and motor complexes. 3/13/17 DRILLIN Continue R/U on CD3-111A, make up GIS, pipe shed. Accept rig @ 06:00 hrs. Rig up choke skid, hardlines and tank. Pull BPV, PT lines, circ out freeze protect. FC, install HP-BPV and test. N/D tree, N/U BOPE and MPDE. 3/14/17 DRILLIN Test MPDE, test BOPE to 250/3800 psi (AOGCC Waived witness.) Pull blanking plug and BPV, R/U and pull and L/D 3%"tubing from 3,115' MD. Installed wear ring. 3/15/17 DRILLIN RIH w/ Bridge Plug assy and set at 3,088' MD. Slip&cut, serviced rig. POOH to surface and M/U 7" Csg cutting assy. RIH tagged CIBP, spaced out, and cut 7" Csg @ 2,921' MD. Attempted to circulate OA with no success. Circulated BU, OWFF w/slight flow. Weighted up to 10.3 ppg and OWFF again w/slight flow. Repeated several times working MW up in 0.5 ppg increments to 11.3 ppg, still observing slight flow. 3/16/17 DRILLIN Weighted mud up to KW of 12 ppg. POOH to next cut depth @ 2,686' MD and cut 7"csg. Observed 720 psi pressure build on OA to confirm cut. Circulated BU and displaced OA to 12 ppg mud. POOH with the cutting assy. Installed and tested 7" SBR. Pulled 7" pack off. M/U 7" spear and pulled hanger to surface. Circulated the OA. Removed spear and L/D. 3/17/17 DRILLIN Pulled 1st casing section to surface, L/D 62 jts, 2,921' of 7"casing. Changed rams to 3 1/2"x6"and tested. RIH w/casing spear assy and engaged 2nd casing segment at 2,921' MD. Attempted to pull casing with no success. Could not release from 7"casing and required the use of surface jars to break free. Tool came free after firing surface jars. 3/18/17 DRILLIN POOH w/spear assy and M/U 7" casing cutter. RIH and cut csg at 2,822' MD. Circulated BU and POOH. M/U spear assy and engage 7" casing at 2,608' MD. Attempted to jar free with no success. Could not release from 7"casing and M/U surface jars to break free. POOH w/spear assy and M/U 3/19/17 DRILLIN Cut 7"casing at 2,739' and 2,782' MD. POOH. M/U spear assy and pulled the 1st 56' section to surface and L/D. Ran back in and retrieved the 2nd 43' long section to surface and L/D. M/U spear assy and started RIH to retrieve the 3rd section. 3/20/17 DRILLIN Engaged the 7"casing fish at 2,789' MD and POOH. L/D 43.3' 7" casing section. M/U 30 jts of 3 1/2" tubing for cmt stinger and RIH to 3,088' MD. Placed KOP w/43.3 bbl of 17 ppg cmt(TOC @ 2,521' MD). Pulled out of cmt plug and circulated well clean. POOH with the cmt stinger and R/U to test BOPE. 3/21/17 DRILLIN L/D Tubing running tools. Tested BOPE. M/U 29 stands of 4" 14#DP and racked back. M/U 8 3/4" motor assy and singled in hole. Tagged hard cmt @ 2,519' MD and drilled out. Kicked off of cmt plug and drilled to 2,777' MD, 2560' TVD. ,.. • i p Cement Detail Report ',2,1°--,,--;:i 0xi l,' t! CD3-111 ConoeoPhillips String: KOP Job: DRILLING SIDETRACK,3/10/2017 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name KOP 3/20/2017 15:30 3/20/2017 16:45 CD3-111 Comment Tested lines to 2000pai and pumped 25.4 bbl of 12.5 ppg MudPush,43.4 bbl of 17 ppg class G cmt,and 4.6 bbl tail 12.5 ppg MudPush. Displaced w/18.8 bbl of 12 ppg brine,under displaced by 1.5 bbl. Cement Stages Stage#0 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? KOP 2,521.0 3,088.0 No No No Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 6 603.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment 1 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 2,521.0 3,088.0 G 43.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 17.00 Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 4/10/2017 • !;, , Operations Sum ! a (with Timelog Depths) u CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/10/2017 3/10/2017 10.00 MIRU MOVE RURD P Blow down steam and water lines, 0.0 0.0 00:00 10:00 swap all mods to cold start generators. Separate motor and pits complexes from substructure.Skid rig floor,jack sub and pull shims.Back sub off CD5- 20 and spot on CD5. SIMOPS-Move GIS,pits and motors around sub,ready to exit CD5 pad. 3/10/2017 3/10/2017 2.00 MIRU MOVE MOB P Begin moving pipe shed first from 0.0 0.0 10:00 12:00 CD5,followed by GIS,pits and motors. SIMOPS-Clean pad and around well. 3/10/2017 3/10/2017 6.00 MIRU MOVE MOB P Continue moving support modules. 0.0 0.0 12:00 18:00 Warm weather and freezing rain making roads very slippery.Slow moving down hill to Nigliq channel crossing @ mile 6.3 utilizing 2 dozers to hold back each module. SIMOPS-Substructure moved.3 miles from CD5,stopped due moving system electrical issue.Mechanic, Tool/Tour pusher,Superintendent and DDI electricians troubleshooting. 3/10/2017 3/11/2017 6.00 MIRU MOVE MOB P Stopped support modules @ 11.3 mile 0.0 0.0 18:00 00:00 ice pad before CD4 road to fuel up. Continue moving,utilize dozers to pull pit complex up to CD4 road,all support modules moving @ mile 13.5 on CD4 road @ midnight. Sub-structure repaired and moving @ 22:00 hrs,at mile 2 coming up to K pad @ midnight.Hydraulic pump had tripped off(1 of 3)backfeeding hydraulic fluid to tank.No indications of trip.Re-set all pumps and resume moving.(Re-booted sub) 3/11/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue with support modules from 0.0 0.0 00:00 06:00 miles 13.5 on CD4 road to ice pad behind CD2 @ mile 16.5 @ 03:00. Park mods on ice pad for sub to go around. Sub on CD5 ice road bypass from mile 2 to mile 4.5,stopping for fuel @ K pad. 3/11/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue moving sub structure on 0.0 0.0 06:00 12:00 CD5 ice road bypass. SIMOPS-Change out centrifuge pump in pump module.Stage MPD equipment in CD3-111 cellar area,lay herculite for rig,build containment around camp and STP.Send updated notification to AOGCC. Page 1/27 Report Printed: 4/10/2017 • a Operations Summary (with Timeiog Depths) P'Y 1 lL..--.,-L'''-'::-. it._ ',{ �R' r CD3-111 ConocoPhillipas Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/11/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue moving sub structure on 0.0 0.0 12:00 18:00 CD5 ice road bypass to ice pad at mile 11.3.Stop to fuel up equipment prior to CD4 road. SIMOPS-Change out centrifuge pump in pump module.Stage MPD equipment in CD3-111 cellar area,lay herculite for rig,build containment around camp and STP.R/U transformer and swap camp to Hi Line power. 3/11/2017 3/12/2017 6.00 MIRU MOVE MOB P Continue moving sub structure down 0.0 0.0 18:00 00:00 CD4 gravel road,@ CD2 intersection 21:00 hrs mile 14.1.Sub @ CD2 ice ramp 15.9 @ midnight. SIMOPS-Lay mats on Tamayayak crossing per Ice road Supervisor/Eng. Peak build snow ramps.Diesel transport staged @ CD3. 3/12/2017 3/12/2017 6.00 MIRU MOVE MOB P Move sub from mile 13.9 to mile 19.5 0.0 0.0 00:00 06:00 on CD3 ice road.Top off fuel @ CD2 ice pad. 3/12/2017 3/12/2017 6.00 MIRU MOVE MOB P Continue moving sub on CD3 ice road 0.0 0.0 06:00 12:00 from mile 19.5 to mile 24.5. 3/12/2017 3/12/2017 6.00 MIRU MOVE MOB P Sub on location CD3 @ 13:00 hrs. 0.0 0.0 12:00 18:00 Spot over well @ 17:00 hrs.Continue to make adjustments to center over well. SIMOPS-Ice road foreman/Eng inspect Tamayayak crossing no damage. 3/12/2017 3/13/2017 6.00 MIRU MOVE MOB P Support modules depart CD2 ice pad 0.0 0.0 18:00 00:00 @ mile 16.5,arrive on location mile 25.1 @ 20:00 hrs.Skid rig floor @ 21:30,move in and spot pit and motor complexes. SIMOPS-Continue centering sub. Move rig mats for spotting modules. Skid rig floor. 3/13/2017 3/13/2017 3.00 MIRU MOVE MOB P Continue to shim pit complex,spot 0.0 0.0 00:00 03:00 pipeshed,work on rig acceptance. 3/13/2017 3/13/2017 3.00 MIRU MOVE RURD P Spot ball mill complex,connect steam, 0.0 0.0 03:00 06:00 air,water,fuel lines electrical.Finalize rig acceptance checklist.Rig accepted @ 06:00. 3/13/2017 3/13/2017 3.00 MIRU WELCTL RURD P R/U tiger tank,choke skid,connect 0.0 0.0 06:00 09:00 choke/flare lines,M/U companion flanges and low torque valves on IA and OA.Thaw lines,pumps. Rig on hi line power @ 09:00. 3/13/2017 3/13/2017 1.50 MIRU WELCTL RURD P Hook up air heater to pipe shed, 0.0 0.0 09:00 10:30 weatherize sub.Tested gas alarms, take on 9.8 ppg brine to rig pits. 3/13/2017 3/13/2017 1.50 MIRU WELCTL MPSP P M/U lubricator,test to 3500 psi. 0.0 0.0 10:30 12:00 Attempt to pull BPV,unsuccessful. 3/13/2017 3/13/2017 1.00 MIRU WELCTL MPSP P PJSM,pull BPV and R/D lubricator. 0.0 0.0 12:00 13:00 Observe ice buildup/plug in master valves causing difficuly pulling BPV. Page 2/27 Report Printed: 4/10/2017 • • Operations Summary (with Timeiog Depths) '' CD3-111 C.oriocoPhil lips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/13/2017 3/13/2017 2.50 MIRU WELCTL RURD P Rig up circulating lines and 0.0 0.0 13:00 15:30 equipment.Blow down lines to tiger tank,steam heat.Blow down and PT with air 120 psi good.Fill with water and PT to 500/3500 psi,good. SITP=0,SIIAP=0 3/13/2017 3/13/2017 0.50 MIRU WELCTL KLWL P Line up and pump 9.8 ppg brine down 0.0 0.0 15:30 16:00 IA,taking returns out tubing to clear out diesel cap.Pump 4 bpm,360 psi through tubing cut @ 3,115'MD. 3/13/2017 3/13/2017 0.50 MIRU WELCTL KLWL P Line up to pump down tubing,taking 0.0 0.0 16:00 16:30 returns out IA circulating out diesel freeze protection.Pumped 4 bpm,500 psi tubing,430 psi IA.With choke full open FCP=500 psi tubing,300 psi IA. Pumped 150 bbl,9.8 ppg brine in and out,410 psi tubing,210 psi IA @ 4 bpm. 3/13/2017 3/13/2017 0.50 MIRU WELCTL OWFF P Shut down,monitor pressure @ 0 psi. 0.0 0.0 16:30 17:00 Blow down lines to choke skid. 3/13/2017 3/13/2017 1.00 MIRU WELCTL OWFF P Open tubing and IA to atmosphere, 0.0 0.0 17:00 18:00 monitor well static for 30 minutes. SIMOPS-R/D circulating lines and equipment. 3/13/2017 3/13/2017 1.00 MIRU WELCTL MPSP P -Set BPV,test to 2000 psi via IA for 10 0.0 0.0 18:00 19:00 minnutes charted.(Testing cement plug,hanger seals and 7"casing. 3/13/2017 3/13/2017 2.50 MIRU WHDBOP NUND P N/D tree,inspect hanger threads- 0.0 0.0 19:00 21:30 good.Install blanking plug, 10'%RH turns.Prep wellhead for N/U. SIMOPS-PJSM for N/U stack and MPD equipment,steam thaw bottom of stack due ice on stump. 3/13/2017 3/13/2017 0.50 MIRU WHDBOP NUND P N/U BOP stack 0.0 0.0 21:30 22:00 3/13/2017 3/14/2017 2.00 MIRU WHDBOP MPDA P PJSM,rig up MPD equipment,flow 0.0 0.0 22:00 00:00 box,flow line,Orbit valve,Katch Kan, hole fill lines,MPD manifold. 3/14/2017 3/14/2017 2.00 MIRU WHDBOP MPDA P Tested rotary head to 200/1200 psi 0.0 0.0 00:00 02:00 against the test plug for 5 min. 3/14/2017 3/14/2017 1.50 MIRU -WHDBOP MPDA P Pulled MPD test plug and installed trip 0.0 0.0 02:00 03:30 nipple. Installed 3.5"test joint. 3/14/2017 3/14/2017 1.50 MIRU WHDBOP -RURD P R/U BOP test equipment,fill stack with 0.0 0.0 03:30 05:00 H2O and purge air. Page 3/27 Report Printed: 4/10/2017 I • 1 ry Operations Summary (with Timeoog Depths) ,,, , CD3-111 CemacaPhil lips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/14/2017 3/14/2017 7.00 MIRU WHDBOP BOPE P Test BOPE with 3.5"and 4W test 0.0 0.0 05:00 12:00 joints.AOGCC Chuck Scheve waived witness.Test Annular to 250/2500 psi, all rams and valves to 250/3500 psi 5 min each charted.3.5"TJ test annular preventer,Choke valves#1,12,13,14, Upper IBOP/Upper VBR,4"Demco kill/CV#9,11,lower IBOP,HCR kill/ CV#5,8,10/CV#4,6,7/CV#2/HCR Choke/Manual choke and kill/Lower VBR's.Change to 4W TJ,test annular!Upper VBR's,4"XT-39 Dart/ Lower VBR's,XT-39 FOSV.Perform accumulator function test.System pressure=2950 psi,Manifold pressure=1500 psi,Annular pressure=750 psi.System pressure after functioning all rams and HCR's=1300 psi.200 psi attained @ 36 sec,Full system recovery @ 184 sec.4 bottle N2 average=2000 psi. Operate remote stations.Pull test joint and test blind rams, Tested gas detecters,function flow meter,check PVT alarms. 3/14/2017 3/14/2017 2.50 MIRU WHDBOP BOPE T The heat trace on the choke line failed 0.0 0.0 12:00 14:30 while testing and froze up. The lines were thawed out before proceeding. 3/14/2017 3/14/2017 0.50 MIRU WHDBOP BOPE P Perform choke draw down test. 0.0 0.0 14:30 15:00 3/14/2017 3/14/2017 1.00 MIRU WHDBOP RURD P R/D test equipment,Blow down lines, 0.0 0.0 15:00 16:00 and pull plug. 3/14/2017 3/14/2017 1.50 SLOT RPCOMP PULL P M/U Landing joint and pull hanger 0.0 0.0 16:00 17:30 free. P/U 100k and weighted 2 min, continued to 110k and hanger came free. 3/14/2017 3/14/2017 0.50 SLOT RPCOMP CIRC P Circulated BU w/6 bpm,230 psi. 0.0 0.0 17:30 18:00 3/14/2017 3/14/2017 5.00 SLOT RPCOMP PULL P Pulled hanger to rig floor,connected 0.0 0.0 18:00 23:00 control line to spool and continued to pull/LD 2 jts of 4.5"tubing,96 jts of 3.5"tubing,SSSV,and 15.8'cut joint. 71 SSCL Bands were recovered. 3/14/2017 3/14/2017 0.50 SLOT RPCOMP WWWH P Installed 9"wear bushing. 0.0 0.0 23:00 23:30 3/14/2017 3/15/2017 0.50 SLOT RPCOMP PULD P R/D tubing equipment and clear floor. 0.0 0.0 23:30 00:00 3/15/2017 3/15/2017 1.00 SLOT RPCOMP RURD P L/D Tubing equipment,control line 0.0 0.0 00:00 01:00 spool,and installed mouse hole. 3/15/2017 3/15/2017 0.50 SLOT PLUG BHAH P M/U CIBP assy as per Baker rep. 0.0 0.0 01:00 01:30 3/15/2017 3/15/2017 5.00 SLOT PLUG -PULD P Singled in the hole with 4"15.7#DP 0.0 3,088.0 01:30 06:30 out of the pipe shed to 3,088'MB 3/15/2017 3/15/2017 0.50 SLOT PLUG MPSP P ,Set CIBP at 3,088'MD. 3,088.0 3,088.0 06:30 07:00 3/15/2017 3/15/2017 0.75 SLOT PLUG CIRC P Circulated s/s @ 6 bpm,300 psi and 3,088.0 3,088.0 07:00 07:45 B/D TD. 3/15/2017 3/15/2017 1.00 SLOT PLUG SLPC P Slip&Cut 80'of drill line. 3,088.0 3,088.0 07:45 08:45 Page 4/27 Report Printed: 4/10/2017 • • i Operations Summary (with Timelog Depths) �� ,. CD3-111 ConocoPhil lips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttKB) 3/15/2017 3/15/2017 0.50 SLOT PLUG SVRG P Serviced TD,blocks,and drawworks. 3,088.0 3,088.0 08:45 09:15 3/15/2017 3/15/2017 1.75 SLOT PLUG TRIP P POOH f/3,088'to surface and L?D 3,088.0 0.0 09:15 11:00 running tool. 3/15/2017 3/15/2017 0.25 SLOT PLUG BHAH P M/U 7"casing cutter assy. 0.0 13.0 11:00 11:15 3/15/2017 3/15/2017 2.75 SLOT PLUG TRIP P RIH fl 13'to 3,088'MD and tagged 13.0 2,921.0 11:15 14:00 CIBP, P/U=100k,S/O=100k. Established circulation at 2.5 bpm, and located collar at 2,899'MD. Continued up to cutting depth of 2,921' MD. 3/15/2017 3/15/2017 1.00 SLOT PLUG CPBO P Cut 7"casing at 2,921'MD w/80 rpm, 2,921.0 2,921.0 14:00 15:00 1k TQ,4.5 bpm,and 700 psi. Observed pressure drop to 250 psi, confirming casing cut. r 3/15/2017 3/15/2017 0.50 SLOT PLUG CIRC P Lined up the OA to take returns, 2,921.0 2,921.0 15:00 15:30 closed annular and attempted to circulate the OA. Staged pressure up to 750 psi at 0.5 bpm with no returns, pushed 0.6 bbl away. Bleed off pressure and observed well,static. (OA 10 psi at surface) 3/15/2017 3/15/2017 2.50 SLOT PLUG CIRC T Circulated BU at 4 bpm, 180 psi,and 2,921.0 2,921.0 15:30 18:00 OWFF with slight flow. Circulated BU at same rate while adding defomer and OWFF with slight flow. circulated a surface to surface,OWFF with slight flow. 3/15/2017 3/15/2017 1.50 SLOT PLUG CIRC T Weighted up brine with viscosifier and 2,921.0 2,921.0 18:00 19:30 barite f/9.8 ppg to 10.3 ppg at 8 bpm, 600 psi. 3/15/2017 3/15/2017 0.50 SLOT PLUG OWFF T POOH f/2,921'to 2,866'MD,BD TD, 2,921.0 2,866.0 19:30 20:00 and OWFF. Slight flow w/increasing rate. 3/15/2017 3/15/2017 0.50 SLOT PLUG CIRC T Circulated 153 bbl at 4 bpm,620 psi. 2,866.0 2,866.0 20:00 20:30 OWFF,slight flow. 3/15/2017 3/15/2017 0.50 SLOT PLUG 'TRIP T RIH and orient at original cut depth of 2,866.0 2,921.0 20:30 21:00 2,921'MD. 3/15/2017 3/15/2017 1.00 SLOT PLUG CIRC T Weighted up f/10.3 ppg to 10.8 ppg at 2,921.0 2,921.0 21:00 22:00 6 bpm,370 psi. 3/15/2017 3/15/2017 0.50 SLOT PLUG OWFF T OWFF,slight flow. 2,921.0 2,921.0 22:00 22:30 3/15/2017 3/16/2017 1.50 SLOT 'PLUG CIRC T Weighted up f/10.8 ppg to 11.3 ppg 2,921.0 2,921.0 22:30 00:00 MW. 3/16/2017 3/16/2017 0.75 SLOT PLUG -CIRC T OWFF,w/slight flow. Circulated BU 2,921.0 2,921.0 00:00 00:45 and continued to see slight flow. 3/16/2017 3/16/2017 1.25 SLOT PLUG CIRC T Weight up f/11.3 ppg to 11.8 ppg w/6 2,921.0 2,921.0 00:45 02:00 bpm,470 psi. 3/16/2017 3/16/2017 0.50 SLOT PLUG OWFF T OWFF,slight flow. 2,921.0 2,921.0 02:00 02:30 3/16/2017 3/16/2017 0.75 SLOT PLUG CIRC T Weight up to 12 ppg MW w/6 bpm, 2,921.0 2,921.0 02:30 03:15 500 psi. 3/16/2017 3/16/2017 0.50 SLOT PLUG TRIP T POOH f/2,921'MD to 2,866'MD. BD 2,921.0 2,866.0 03:15 03:45 TD and OWFF,well static. 3/16/2017 3/16/2017 0.50 SLOT PLUG TRIP P POOH f/2,866'to 2,679'MD and 2,866.0 2,686.0 03:45 04:15 engaged pumps. S/O to first casing collar at 2,688'MD and P/U 3'to cut depth @ 2,686'MD Page 5/27 Report Printed: 4/10/2017 • • Operations Summary (with V imelog Depths) JP2 !_fit _;,i, CD3-111 ConoeoPhil liiss Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/16/2017 3/16/2017 1.00 SLOT PLUG CPBO P Cut 7"Csg @ 2,686'MD wf 175 gpm, 2,686.0 2,686.0 04:15 05:15 800 psi,80 rpm,and 2k TQ. Observed 730 psi build on the OA, indicating csg cut. 3/16/2017 3/16/2017 0.75 SLOT PLUG 'CIRC P Circulated BU in 7"csg @ 175 gpm, 2,686.0 2,686.0 05:15 06:00 790 psi. 3/16/2017 3/16/2017 1.25 SLOT PLUG DISP P Closed annular and lined up to take 2,686.0 2,686.0 06:00 07:15 returns from the OA to the choke and displaced out 50 bbl of diesel,-40 bbl of H2O with 12 ppg mud. 3/16/2017 3/16/2017 1.25 SLOT PLUG CIRC P Circulated 1.5 BU through the OA @ 2 2,686.0 2,686.0 07:15 08:30 bpm,270 psi. 3/16/2017 3/16/2017 0.50 SLOT PLUG CIRC P Open the annular,close OA,and 2,686.0 2,686.0 08:30 09:00 circulate BU in 7"csg. 3/16/2017 3/16/2017 0.25 SLOT PLUG TRIP P POOH f/2,686'to 2,676'MD,BD TD. ' 2,686.0 2,676.0 09:00 09:15 3/16/2017 3/16/2017 0.75 SLOT PLUG OWFF P OWFF,well static. 2,676.0 2,676.0 09:15 10:00 3/16/2017 3/16/2017 1.75 SLOT PLUG TRIP 'P POOH f/2,676'to 13'MD w/cutting 2,676.0 13.0 10:00 11:45 assy. 3/16/2017 3/16/2017 0.25 SLOT PLUG BHAH P L/D 7"casing cutting assy. 13.0 0.0 11:45 12:00 3/16/2017 3/16/2017 3.00 SLOT PLUG BOPE P Changed out BOP rams to 7"SBRs. 0.0 0.0 12:00 15:00 Installed test plug w/7"test joint and R/U testing equipment. 3/16/2017 3/16/2017 1.00 SLOT PLUG BOPE P Tested annular to 250/2500 psi and 0.0 0.0 15:00 16:00 attempted to test rams. Observed loss of pressure at the BOP speed head flange. 3/16/2017 3/16/2017 1.50 SLOT PLUG BOPE T Tightened flange segments on the 0.0 0.0 16:00 17:30 speed head. 3/16/2017 3/16/2017 0.50 SLOT PLUG BOPE T Tested annular to 250/2500 psi,7" 0.0 0.0 17:30 18:00 rams to 2500/3500 psi. TEST GOOD. 3/16/2017 3/16/2017 1.00 SLOT PLUG 'BOPE P Pulled test joint and plug. R/D test 0.0 0.0 18:00 19:00 equipment,clean and cleared floor. 3/16/2017 3/16/2017 1.00 SLOT PLUG PULL P M/U 7"pack off retrieval tool and RIH. 0.0 0.0 19:00 20:00 set down 10k on pack off and removed lock down screws. Pulled to surface and L/D retrieval tool. 3/16/2017 3/16/2017 0.50 SLOT PLUG RURD P Set 10 3/8"ID wear ring. 0.0 0.0 20:00 20:30 3/16/2017 3/16/2017 1.00 SLOT PLUG PULL P M/U 7"casing spear and engage 7" 0.0' 0.0 20:30 21:30 casing hanger. pulled hanger free w/ 122k and pulled to rig floor. P/U= 115k. 3/16/2017 3/16/2017 1.50 SLOT PLUG CIRC P Circulate surface to surface staging up 0.0 0.0 21:30 23:00 from 2 bpm to 5 bpm,190 psi. Pumped 25 bbl deep clean pill. SimOps,R/U 7"casing equipment. 3/16/2017 3/17/2017 1.00 SLOT PLUG BHAH P Release casing spear and L/D. BD 0.0 0.0 23:00 00:00 TD. SimOps finish R/U casing tools. 3/17/2017 3/17/2017 0.50 SLOT PLUG OWFF P OWFF,well static. 0.0 0.0 00:00 00:30 3/17/2017 3/17/2017 4.50 SLOT PLUG PULL P POOH and L/D 62 jnts of 7"casing. 0.0 0.0 00:30 05:00 Jnt#62 was cut and flared out. 3/17/2017 3/17/2017 0.50 SLOT PLUG RURD P Drained stack and cleaned rig floor. 0.0 0.0 05:00 05:30 3/17/2017 3/17/2017 1.00 SLOT PLUG BOPE P Changed upper rams to 3 1/2"x 6" 0.0 0.0 05:30 06:30 variable rams. Page 6/27 Report Printed: 4/10/2017 Aerations Summary (with Timelog e the ' CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/17/2017 3/17/2017 0.50 SLOT PLUG BOPE P Remove wear ring and installed test 0.0 0.0 06:30 07:00 plug as per FMC. 3/17/2017 3/17/2017 0.75 SLOT PLUG BOPE P R/U BOP test equipment and fill stack 0.0 0.0 07:00 07:45 w/H2O. 3/17/2017 3/17/2017 1.50 SLOT PLUG BOPE P Test annular to 250/2500 psi and 0.0 0.0 07:45 09:15 3.5"x6"ram to 250/3500 psi with both 3 1/2"and 4"test joints. RID test equipment. 3/17/2017 3/17/2017 0.50 SLOT PLUG BOPE P Remove test plug and install 10"ID 0.0 0.0 09:15 09:45 wear ring. 3/17/2017 3/17/2017 0.50 SLOT PLUG BHAH P P/U fishing equipment to rig floor. 0.0 0.0 09:45 10:15 3/17/2017 3/17/2017 2.50 SLOT PLUG BHAH P M/U 7"spear assy as per Baker rep to 0.0 235.0 10:15 12:45 235'MD. 3/17/2017 3/17/2017 1.25 SLOT PLUG TRIP P RIH f/235'to 2,421'MD with spear 235.0 2,421.0 12:45 14:00 assy. 3/17/2017 3/17/2017 0.25 SLOT PLUG WASH P Break circulation and wash down f/ 2,421.0 2,612.0 14:00 14:15 2,421'to 2,612'MD w/3 bpm,150 psi. 3/17/2017 3/17/2017 2.25 SLOT PLUG FISH P M/U stand#26 and engage 7"casing 2,612.0 2,683.0 14:15 16:30 fish at 2,683'MD.Attempted to pull free staging up to 200k overpull WI jars and 300k straight pull,no go. Held 200 psi w/200k overpull w/jars and 250 strait pull,no go. 3/17/2017 3/17/2017 1.75 SLOT PLUG FISH T Attempted to release 7"spear with 10k 2,683.0 2,683.0 16:30 18:15 TQ and 175k P/U,no go. BD TD, Staged up overpull and fired jars @ 200k,Worked down weight. 3/17/2017 3/17/2017 0.75 SLOT PLUG SFTY T Performed derrick inspection due to 2,683.0 2,683.0 18:15 19:00 jarring. 3/17/2017 3/17/2017 2.00 SLOT PLUG FISH T Continued attempting to release 7" 2,683.0 2,683.0 19:00 21:00 spear w/150k overpull and 5k TQ. working up to 325k straight overpull. Alternating between firing jars and hitting down. 3/17/2017 3/17/2017 1.00 SLOT PLUG 'SFTY 'T Performed derrick inspection due to 2,683.0 2,683.0 21:00 22:00 jarring. 3/17/2017 3/17/2017 0.75 SLOT PLUG FISH T Continued to attempt to free 7"spear 2,683.0 2,683.0 22:00 22:45 w/175k overpull and firing jars. 3/17/2017 3/17/2017 1.00 SLOT PLUG PULD T P/U Baker surface jars to rig floor and 2,683.0 2,683.0 22:45 23:45 make up to DP. 3/17/2017 3/18/2017 0.25 SLOT PLUG FISH 'T Fired surface jars w/100k overpull 2,683.0 2,683.0 23:45 00:00 and released 7"spear. Confirmed free w/125k straight pull. 3/18/2017 3/18/2017 0.50 SLOT PLUG PULD P L/D surface jars and XOs 2,683.0 2,683.0 00:00 00:30 3/18/2017 3/18/2017 0.75'SLOT PLUG CIRC P Circulated BU w 5 bpm,200 psi. 2,683.0 2,683.0 00:30 01:15 SimOps,performed derrick inspection. 3/18/2017 3/18/2017 0.75 SLOT PLUG 'OWFF P OWFF,well static. BD TD. 2,683.0 2,683.0 01:15 02:00 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/2,670'to 235'MD w/spear 2,683.0 235.0 02:00 03:30 assy. 3/18/2017 3/18/2017 0.25 SLOT PLUG OWFF P OWFF,well static. 235.0 235.0 03:30 03:45 3/18/2017 3/18/2017 1.50 SLOT PLUG BHAH P Rack back drill collars and LID spear 235.0 0.0 03:45 05:15 assy as per baker. Clean and clear floor. Page 7/27 Report Printed: 4/10/2017 • , 1 e rations Summary (with Thmolo Depths) - ,., : ' CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/18/2017 3/18/2017 0.25 SLOT PLUG BHAH P M/U 7"cutting assy w/new cutters as 0.0 13.0 05:15 05:30 per Baker. 3/18/2017 3/18/2017 2.25 SLOT PLUG TRIP P RIH on 4"DP from derrick f/13'to 13.0 2,820.0 05:30 07:45 2,820'MD. P/U=97,S/0=95. 3/18/2017 3/18/2017 0.75 SLOT PLUG CPBO P Located collar 2,819'MD while 2,820.0 2,822.0 07:45 08:30 washing down w/2 bpm,250 psi,and 5/0 5k. Dropped cutters 3'below collar at 2,822'MD and cut casing w/ 4.3 bpm,800 psi,80 rpm,2.5k TQ. Observed a 560 psi pressure drop, indicating a clean cut. 3/18/2017 3/18/2017 0.50 SLOT PLUG CIRC P Circulated BU w/6 bpm,370 psi. 2,822.0 2,822.0 08:30 09:00 SimOps,mobilized spear assy to rig floor. 3/18/2017 3/18/2017 0.50 SLOT PLUG OWFF P OWFF,Well static. R/B a stand to 2,822.0 2,771.0 09:00 09:30 2,771'MD and BD TD. 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/2,771'to 13'MD. 2,771.0 13.0 09:30 11:00 3/18/2017 3/18/2017 0.50 SLOT PLUG BHAH P L/D cutting assy and clear rig floor. 13.0 0.0 11:00 11:30 3/18/2017 3/18/2017 1.75 SLOT PLUG BHAH P M/U 7"spear assy as per Baker. 0.0 230.0 11:30 13:15 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P RIH f/230'to 2,608'MD. 230.0 2,608.0 13:15 14:45 3/18/2017 3/18/2017 1.25 SLOT PLUG FISH P Engage fish at 2,692'MD and set 2,608.0 2,692.0 14:45 16:00 down 5k. P/U to 150k and confirmed engagement. attempted to free fish w/ 200k overpull while firing jars. worked up to 300k over straight pull with now success. 3/18/2017 3/18/2017 0.75 SLOT PLUG SVRG P Performed a derrick inspection due to 2,692.0 2,692.0 16:00 16:45 jarring. 3/18/2017 3/18/2017 0.75 SLOT PLUG FISH P Attempt to release from 7"casing.w/ 2,692.0 2,692.0 16:45 17:30 200k pull and firing jars. worked up to 300k straight pull. Applied downward force w/5k TQ in string. No Go. 3/18/2017 3/18/2017 0.50 SLOT PLUG FISH P P/U surface jar and a single. M/U to 2,692.0 2,692.0 17:30 18:00 string and fire with 120k P/U to release spear. 3/18/2017 3/18/2017 0.50 SLOT PLUG RURD P R/D surface jars and L/D. 2,692.0 2,692.0 18:00 18:30 3/18/2017 3/18/2017 1.00 SLOT PLUG 'CIRC P Circulate BU at 5 bpm,200 psi. 2,692.0 2,692.0 18:30 19:30 SimOps,perform derrick inspection. B/D TD and OWFF. 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/2,692'to 230'MD. 2,692.0 230.0 19:30 21:00 3/18/2017 3/18/2017 1.00 SLOT PLUG -BHAH P UD spear assy in 2 segments and R/D 230.0 0.0 21:00 22:00 drill collars. 3/18/2017 3/18/2017 0.50 SLOT 'PLUG BHAH P M/U 7"cutting assy. 0.0 13.0 22:00 22:30 3/18/2017 3/19/2017 1.50 SLOT PLUG TRIP P RIH f/13'to 2,782'MD on 4"15.7# 13.0 2,782.0 22:30 00:00 DP. 3/19/2017 3/19/2017 0.50 SLOT PLUG CPBO P Positioned cutter at 2,782'MD and cut 2,782.0 2,782.0 00:00 00:30 w/4.3 bpm,800 psi,and 24.K TQ. Observed a 530 psi drop and confirmed a clean cut. 3/19/2017 3/19/2017 0.75 SLOT PLUG CIRC P Circulated BU and OWFF. 2,782.0 2,782.0 00:30 01:15 Page 8/27 Report Printed: 4/10/2017 • •erations Summary (with Timeiog Depths) CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/19/2017 3/19/2017 0.50 SLOT PLUG CPBO P Positioned cutter at 2,739'and made 2,782.0 2,739.0 01:15 01:45 5th cut,4.3 bpm,800 psi,2.3k TQ, and 80 rpm. Observed 530 psi pressure drop and confirmed cut. 3/19/2017 3/19/2017 0.75 SLOT PLUG CIRC P Circulated BU and OWFF. BD TD. 2,739.0 2,739.0 01:45 02:30 3/19/2017 3/19/2017 1.50 SLOT PLUG TRIP P POOH f/2,739'to 13'MD w/cutting 2,739.0 13.0 02:30 04:00 assy. 3/19/2017 3/19/2017 0.25 SLOT PLUG BHAH -P LID cutter assy as per Baker. Cutters 13.0 0.0 04:00 04:15 were in good condition after a total of 3 cuts. 3/19/2017 3/19/2017 1.00 SLOT PLUG BHAH P P/U 7"spear assy to 230'MD. 0.0 230.0 04:15 05:15 3/19/2017 3/19/2017 1.25 SLOT PLUG TRIP P RIH f/230'to 2,512'MD on 4"DP. 230.0 2,512.0 05:15 06:30 3/19/2017 3/19/2017 0.50 SLOT PLUG WASH P Washed down ff 2,512'to 2,608'MD 2,512.0 2,608.0 06:30 07:00 w/3 bpm,140 psi,PIU 107,S/O= 100. 3/19/2017 3/19/2017 1.00 SLOT PLUG FISH P Engage fish at 2,686'MD and P/U 2,608.0 2,608.0 07:00 08:00 115k to confirm. Worked parameters up and fired jars at 190k and pulled free to 160k. Established circulation w/1 bpm,390 psi. Pulled to 2,608' MD and CBU at 7 bpm,340 psi. 3/19/2017 3/19/2017 0.25 SLOT PLUG OWFF 'P OWFF,Well static. BD TD. 2,608.0 2,608.0 08:00 08:15 3/19/2017 3/19/2017 1.75 SLOT PLUG TRIP P POOH with 7"casing fish f/2,608'to 2,608.0 230.0 08:15 10:00 230'MD. 3/19/2017 3/19/2017 0.75 SLOT PLUG BHAH P Rack back drill collars and UD jars. 230.0 0.0 10:00 10:45 3/19/2017 3/19/2017 1.00 SLOT PLUG PULD P R/U 7"casing equipment and L/D 53' 0.0 0.0 10:45 11:45 7"casing fish. clear and clean rig floor. 3/19/2017 3/19/2017 0.75 SLOT PLUG BHAH P M/U 7"casing spear assy as per 0.0 230.0 11:45 12:30 Baker. 3/19/2017 3/19/2017 1.00 SLOT -PLUG TRIP P RIH with spear assy f/230'to 2,608' 230.0 2,608.0 12:30 13:30 MD. 3/19/2017 3/19/2017 1.25 SLOT *PLUG WASH P Wash down f/2,608'to 2,736'MD w/ 2,608.0 2,736.0 13:30 14:45 6.5 bpm,550 psi,P/U=106,3/0= 100. 3/19/2017 3/19/2017 0.75 SLOT PLUG FISH 'P Engaged 7"casing fish at 2,745'MD 2,736.0 2,643.0 14:45 15:30 and P/U to 125k to confirm. staged up to 150k overpull firing jars and P/U 225k over to free fish.P/U to 2,643' MD to confirm. 3/19/2017 3/19/2017 0.75 SLOT PLUG CIRC -P Circulated 2 BU at 7 bpm,350 psi. 2,643.0 2,643.0 15:30 16:15 SimOps,performed derrick inspection. 3/19/2017 3/19/2017 0.50 SLOT -PLUG -OWFF P OWFF,Well static. 2,643.0 2,643.0 16:15 16:45 3/19/2017 3/19/2017 1.75 SLOT PLUG TRIP P POOH with 7"casing fish f/2,643'to 2,643.0 230.0 16:45 18:30 230'MD. 3/19/2017 3/19/2017 2.50 SLOT PLUG BHAH P L/D Jars,RIB drill collars and released 230.0 0.0 18:30 21:00 from fish. 20k TQ and down weight were required to break spear out. 3/19/2017 3/19/2017 0.50 SLOT PLUG PULD P L/D 44.24'7"casing fish. 0.0 0.0 21:00 21:30 3/19/2017 3/19/2017 1.00 SLOT PLUG BHAH P M/U spear assy as per Baker. 0.0 230.0 21:30 22:30 Page 9/27 Report Printed: 4/10/2017 • • Operations Summary 1_ o (with Tirrr e o Depths) 4,404.1., CD3-111 Canoc Phillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/19/2017 3/19/2017 1.25 SLOT PLUG TRIP P RIH with spear assy f/230'to 2,608' 230.0 2,608.0 22:30 23:45 MD. 3/19/2017 3/20/2017 0.25 SLOT PLUG WASH P Wash down f/2,608'MD to 2,703'MD 2,608.0 2,703.0 23:45 00:00 w/6.5 bpm,330 psi. 3/20/2017 3/20/2017 2.25 SLOT PLUG FISH P Wash down f/2,703'MD to 2,737'MD 2,608.0 2,703.0 00:00 02:15 w/6.5 bpm,330 psi.Observed slight pack offs f/2,737'to 2,739'MD. rotated down to 2,766'MD. shut down pumps and engaged 7"casing at 2,787'MD. P/U 125k to confirm spear engaged. jarred 5 times w/250k and pulled fish free w/330k. P/U to 2,703' and confirmed the spear had the fish. 3/20/2017 3/20/2017 1.75 SLOT PLUG CIRC P Circulated 2 BU w/4 bpm,350 psi. 2,703.0 2,703.0 02:15 04:00 BD TD and OWFF. 3/20/2017 3/20/2017 2.50 SLOT PLUG TRIP P POOH f/2,703'to 230'MD. RIB 4" 2,703.0 230.0 04:00 06:30 DP. 3/20/2017 3/20/2017 2.00 SLOT PLUG BHAH P LID drill collars,spear assy and 43' 230.0 0.0 06:30 08:30 long 7"casing fish as per Baker. 3/20/2017 3/20/2017 2.00 SLOT PLUG RURD P LID fishing tools from rig floor and 0.0 0.0 08:30 10:30 change out 7"casing tools for 3 1/2" tubing tools. M/U XO to TIW valve. 3/20/2017 3/20/2017 1.75 SLOT PLUG PULD P P/U 30 jts of 3 1/2"tubing and RIH 0.0 926.0 10:30 12:15 with mule shoe for cmt stinger. M/U XO to 4"XT39 and rig down 3 1/2" equipment. 3/20/2017 3/20/2017 2.75 SLOT PLUG TRIP P RIH w/cmt stinger on 4"14#DP f/ 926.0 3,088.0 12:15 15:00 944'to 3,088'MD and tag CIBP w/5k. 3/20/2017 3/20/2017 0.50 SLOT -PLUG RURD P R/U headpin.swing,hoses,valves, 3,088.0 3,088.0 15:00 15:30 and cmt line. filled lines w/mud. 3/20/2017 3/20/2017 1.25 SLOT PLUG CMNT P Tested lines to 2000 psi and pumped 3,088.0 3,088.0 15:30 16:45 25.4 bbl of 12.5 ppg spacer,43.4 bbl 17 ppg cement,and 4.6 bbl of 12.5 ppg tail spacer. displaced w/18.8 bbl of 12 ppg brine. Balanced plug in place @ 16:45. 3/20/2017 3/20/2017 0.75 SLOT PLUG TRIP P R/D head pin and cmt lines. Pull out 3,088.0 2,521.0 16:45 17:30 of cmt plug f/3,088,to 2,521'MD. 3/20/2017 3/20/2017 2.25 SLOT PLUG CIRC P Drop nerf ball and circulate @ 7 bpm, 2,521.0 2,452.0 17:30 19:45 210 psi,and pump nut plug sweep. 3/20/2017 3/20/2017 1.25 SLOT PLUG `OWFF P OWFF,well static. Pumped 15 bbl, 2,452.0 2,452.0 19:45 21:00 13.3#dry job to stop DP overflowing. 3/20/2017 3/20/2017 0.75 SLOT PLUG TRIP P POOH f/2,452'to 944'MD. 2,452.0 944.0 21:00 21:45 3/20/2017 3/20/2017 2.00'SLOT PLUG PULD P L/D 30 jts of 3 1/2"tubing. 944.0 0.0 21:45 23:45 3/20/2017 3/21/2017 0.25 SLOT PLUG RURD "P R/D tubing running tools. 0.0 0.0 23:45 00:00 3/21/2017 3/21/2017 0.50 SLOT PLUG RURD P R/D tubing running tools and clear 0.0 0.0 00:00 00:30 floor. 3/21/2017 3/21/2017 1.00 SLOT PLUG WWWH P Removed wear ring as per FMC and 0.0 0.0 00:30 01:30 flushed stack w/10 bpm,20 psi,and 5 rpm. BD TD. 3/21/2017 3/21/2017 1.00 SLOT WHDBOP RURD P Installed test plug and 4"test joint. 0.0 0.0 01:30 02:30 Filled stack w/H2O and purged it of air. Page 10/27 Report Printed: 4/10/2017 4 +f; perat ons Summary (with Timeiog Depths) , 0,4— --47-t-:.,,,- ' , !:,- --.,--. 4.stid CD3-111 ConocoPhiilips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/21/2017 3/21/2017 4.50 SLOT WHDBOP BOPE P Test BOPE with 4"test joint.AOGCC 0.0 0.0 02:30 07:00 Brian Bixby witnessed.Test Annular to 250/2500 psi,all rams and valves to 250/3800 psi 5 min each charted.4" TJ test annular preventer,Choke valves#1,12,13,14,Upper IBOP/ Upper VBR,4"Demco kill/CV#9,11, lower IBOP,HCR kill/CV#5,8,10/CV #4,6,7/CV#2/HCR Choke/Manual choke and kill/Lower VBR's. Perform accumulator function test.System pressure=2900 psi,Manifold pressure=1450 psi,Annular pressure=850 psi.System pressure after functioning all rams and HCR's=1300 psi.200 psi attained @ 32 sec,Full system recovery @ 186 sec.4 bottle N2 average=2000 psi. Operate remote stations.Pull test joint and test blind rams, Tested gas detecters,function flow meter,check PVT alarms. _ 3/21/2017 3/21/2017 1.00 SLOT WHDBOP RURD P RID BOP test equipment and removed 0.0 0.0 07:00 08:00 test plug. Installed 10"ID wear ring and bleed down lines. 3/21/2017 3/21/2017 1.00 SLOT PLUG RURD P Mobilize BHA components to the rig 0.0 0.0 08:00 09:00 floor and clear floor. Removed skate roller. 3/21/2017 3/21/2017 3.00 SLOT PLUG PULD P M/U and rack back 29 stands of 4" 0.0 0.0 09:00 12:00 14#DP. 3/21/2017 3/21/2017 0.75 SLOT -PLUG PULD P P/U fishing tools to rig floor and break 0.0 0.0 12:00 12:45 off XOs from surface jars. 3/21/2017 3/21/2017 1.75 SLOT PLUG BHAH P M/U motor drill out assy as per SLB to 0.0 447.0 12:45 14:30 447'MD. 3/21/2017 3/21/2017 2.00 SLOT PLUG PULD P Singled in the hole w/4"14#DP from 447.0 2,048.0 14:30 16:30 the pipe shed f/447'to 2,048'MD. 3/21/2017 3/21/2017 0.25 SLOT PLUG TRIP P RIH f/2,048'to 2,331'MD 2,048.0 2,331.0 16:30 16:45 3/21/2017 3/21/2017 0.50 SLOT PLUG DHEQ P Shallow tested MWD tools w/450 2,331.0 2,331.0 16:45 17:15 gpm, 1190 psi. 3/21/2017 3/21/2017 0.25 SLOT PLUG RURD P R/U casing test equipment and tested 2,331.0 2,331.0 17:15 17:30 lines to 2500 psi. 3/21/2017 3/21/2017 0.75 SLOT PLUG PRTS P Pressure tested casing to 2500 psi for 2,331.0 2,331.0 17:30 18:15 30 min. 3/21/2017 3/21/2017 0.25 SLOT PLUG RURD P R/D casing test equipment and BD 2,331.0 2,331.0 18:15 18:30 lines. 3/21/2017 3/21/2017 0.75 INTRM1 DRILL WASH P Wash down f/2,331'to 2,519'MD at 2,331.0 2,519.0 18:30 19:15 450 gpm,1260 psi and tagged TOC ©2,519'MD. 3/21/2017 3/21/2017 3.00 INTRM1 DRILL 'DRLG P Drill out cmt f/2,519'to casing shoe at 2,519.0 2,721.0 19:15 22:15 2,721'MD. 500 gpm, 1560 psi,50 rpm,4k TQ. 3/21/2017 3/22/2017 1.75 INTRM1 DRILL DDRL P Drilled f/2,721'to 2,777'MD,kicking 2,721.0 2,777.0 22:15 00:00 off of cmnt plug. 3/22/2017 3/22/2017 7.00 INTRM1 DRILL DDRL .P Drill f/2,777'to 3,274'MD w/575 2,777.0 3,274.0 00:00 07:00 gpm, 1800 psi,50 rpm,5k TQ. Pumped 25 bbl of 11 ppg spacer and displaced well to 9.6 ppg LSND on the fly. 2,958'TVD. Page 11/27 Report Printed: 4/10/2017 •erations Summary (with Timek Depths) ,,tart CD3-111 ConacoPF%iilips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start lime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/22/2017 3/22/2017 0.75 INTRM1 DRILL CIRC P Pumped 31 bbl nut plug sweep and 3,274.0 3,274.0 07:00 07:45 circulated well clean w/575 gpm, 1540 psi,and 50 rpm. 3/22/2017 3/22/2017 0.25 INTRM1 DRILL OWFF P OWFF,Well Static. 3,274.0 3,274.0 07:45 08:00 3/22/2017 3/22/2017 1.25 INTRM1 DRILL SRVY P Drop gyro tool and pump down w/3 3,274.0 2,804.0 08:00 09:15 bpm,170 psi,and land above the float. Took gyro shots every 30'f/ 3,274'to 2,803'MD. 3/22/2017 3/22/2017 2.25 INTRM1 DRILL TRIP P POOH f/2,803'to 448'MD. 2,804.0 448.0 09:15 11:30 3/22/2017 3/22/2017 1.50 INTRM1 DRILL BHAH P RIB HWDP and LID motor assy. 448.0 0.0 11:30 13:00 3/22/2017 3/22/2017 2.25 INTRM1 DRILL BHAH P M/U 8 3/4"rotary steerable BHA as 0.0 484.0 13:00 15:15 per SLB. 3/22/2017 3/22/2017 0.75 INTRM1 DRILL TRIP P RIH f/484'to 1,895'MD. 484.0 1,895.0 15:15 16:00 3/22/2017 3/22/2017 0.50 INTRM1 DRILL DHEQ P Shallow test MWD w/450 gpm,930 1,895.0 1,895.0 16:00 16:30 psi. BD TD. 3/22/2017 3/22/2017 0.50 INTRM1 DRILL TRIP -P RIH f/1,895'to 2,650'MD. 1,895.0 2,650.0 16:30 17:00 3/22/2017 3/22/2017 1.00 INTRM1 DRILL SLPC P Slip and Cut 45'of drill line. 2,650.0 2,650.0 '17:00 18:00 3/22/2017 3/22/2017 0.50 INTRMI DRILL SVRG P Service TD and drawworks. 2,650.0 2,650.0 18:00 18:30 3/22/2017 3/22/2017 1.25 INTRM1 DRILL REAM P Washed down f/2,650'to 3,246'MD 2,650.0 3,246.0 18:30 19:45 due to weight w/3 bpm,240 psi,20 rpm,3.5k TQ. 3/22/2017 3/22/2017 0.50 INTRM1 -DRILL DHEQ P Took initial parameters at 600 gpm, 3,246.0 3,246.0 19:45 20:15 1870 psi,40 rpm,TRPM 3125,and 3.6k TQ. Dropped 1.25"ball and pumped down w/150 gpm,230 psi, 30 rpm. Observed shear w/440 psi at 250 stks. Increased flow to 600 gpm and compared parameters. 1520 psi, 40 rpm,TRPM 2578,3.5k TQ. Turned pumps off and S/O w/8k WOB. REAMED OPEN 3/22/2017 3/23/2017 3.75 INTRM1 DRILL DDRL P Drill f/3,274'to 3,782'MD,pumping 3,246.0 3,782.0 20:15 00:00 high vis sweep every other stand. 3/23/2017 3/23/2017 8.75 INTRM1 DRILL DDRL P Drill f/3,782'to 5,011'MD,pumping 3,782.0 5,011.0 00:00 08:45 high vis sweep every other stand. 3/23/2017 3/23/2017 1.00 INTRMI DRILL CIRC P Pumped low vis 24 bbl anti jamming 5,011.0 5,011.0 08:45 09:45 pill to trouble shoot MWD issues. 3/23/2017 3/23/2017 1.50 INTRM1 DRILL DDRL P Drilled f/5,011'to 5,111'MD,trouble 5,011.0 5,111.0 09:45 11:15 shooting MWD communication issues w/low vis sweeps. Communication with tool continued to decline. 3/23/2017 3/23/2017 0.25 -INTRM1 DRILL TRIP 'T Racked back a stand to 5,106'MD 5,111.0 5,106.0 11:15 11:30 3/23/2017 3/23/2017 1.50 INTRM1 DRILL CIRC T Circulated at 750 gpm,3110psi and 5,106.0 4,917.0 11:30 13:00 160 rpm 6k TQ,while trying to establish communication with MWD. No success. BD TD. 3/23/2017 3/23/2017 1.75 INTRM1 DRILL TRIP T POOH f/4,917'to 3,499'MD. 4,917.0 3,499.0 13:00 14:45 3/23/2017 3/23/2017 0.25 INTRM1 DRILL OWFF T OWFF,Well Static. 3,499.0 3,499.0 14:45 15:00 Page 12/27 Report Printed: 4/10/2017 • • Operati ins Summary (with Tirnelog Depths) Pl . t ' ,' } w - CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/23/2017 3/23/2017 3.50 INTRM1 DRILL TRIP T POOH f/3,499'to 484'MD. 3,499.0 484.0 15:00 18:30 Encountered tight spots @ 2,964', 2,933',and 2,792'MD. 3/23/2017 3/23/2017 1.75 INTRM1 DRILL BHAH T RIB HWDP and drill collars. L/D MWD 484.0 0.0 18:30 20:15 and power drive. 3/23/2017 3/23/2017 0.50 INTRM1 DRILL GLEN T Clear and clean rig floor of clay. 0.0 0.0 20:15 20:45 3/23/2017 3/23/2017 1.00 INTRMI DRILL BHAH T M/U 8 3/4"BHA w/new MWD tools. 0.0 485.0 20:45 21:45 3/23/2017 3/23/2017 0.75 INTRMI DRILL TRIP 'T RIH f/485'to 1,896'MD. 485.0 1,896.0 21:45 22:30 3/23/2017 3/23/2017 0.50 INTRMI DRILL DHEQ T Shallow tested MWD w/550 gpm, 1,896.0 1,896.0 22:30 23:00 1210 psi. BD TD. 3/23/2017 3/24/2017 1.00 INTRM1 DRILL TRIP T RIH f/1,896'to 3,123'MD. 1,896.0 3,123.0 23:00 00:00 3/24/2017 3/24/2017 1.75 INTRM1 DRILL TRIP T RIH f/3,123'to 5,012'MD. 3,123.0 5,012.0 00:00 01:45 3/24/2017 3/24/2017 0.50 INTRM1 DRILL REAM T Ream down f/5,012'to 5,111'MD w/ 3,123.0 5,111.0 01:45 02:15 600 gpm,2400 psi,100 rpm,and 5.5k TQ. 3/24/2017 3/24/2017 9.75 INTRM1 DRILL DDRL P Drilled f/5,111'to 6,294'MD,5,620 5,111.0 5,620.0 02:15 12:00 TVD. 3/24/2017 3/24/2017 2.25 INTRMI DRILL DDRL P Drilled f/6,294'to 6,523'MD. 5,620.0 6,523.0 12:00 14:15 3/24/2017 3/24/2017 1.00 INTRMI -DRILL CIRC P Circulated 2 BU at 750 gpm,3800 psi, 6,523.0 6,523.0 14:15 15:15 140 rpm,7k TQ. 3/24/2017 3/24/2017 0.75 INTRM1 DRILL 'MPDA P Removed trip nipple and installed 6,523.0 6,523.0 15:15 16:00 RCD bearing. Rotated at 50-100 rpm to break in bearing. 3/24/2017 3/25/2017 8.00 INTRM1 DRILL DDRL P Drilled f/6,523'to 7,187'MD,6,391' 6,523.0 7,187.0 16:00 00:00 TVD. Weighted up to 10.3 ppg on the fly,as per plan. 3/25/2017 3/25/2017 11.00 1NTRM1 DRILL DDRL P Drilled f/7,187'to 8,004'MD. 7,187.0 8,004.0 00:00 11:00 3/25/2017 3/25/2017 0.50 INTRM1 DRILL SVRG P Lubricated TD and changed out swab 8,004.0 8,004.0 11:00 11:30 and liner on pump#2. Circulated mud at 400 gpm, 1710 psi,100 rpm,and 7.5k TQ. 3/25/2017 3/25/2017 0.25 INTRM1 DRILL CIRC P Took slow pump rates. 8,004.0 8,004.0 11:30 11:45 3/25/2017 3/25/2017 0.25 INTRMI 'DRILL DDRL P Drilled f/8,004'to 8,011'MD,6.853' 8,004.0 8,011.0 11:45 12:00 TVD. 3/25/2017 3/26/2017 12.00 INTRMI DRILL DDRL P Drilled f/8,011'to 8,419'MD,6,927' 8,011.0 8,419.0 12:00 00:00 TVD. 3/26/2017 3/26/2017 3.00 INTRM1 DRILL DDRL P Drilled f/8,450'to TD of 8,540'MD, 8,419.0 8,540.0 00:00 03:00 6,935'TVD. 3/26/2017 3/26/2017 5.75 INTRMI CASING CIRC P Circulated well clean w/8 BU while 8,540.0 8,424.0 03:00 08:45 POOH to 8,424'MD. Weighted up to a 10.8 ppg MW while cleaning hole. 660 gpm,4030 psi,150 rpm,9k TQ. 3/26/2017 3/26/2017 0.75 INTRM1 CASING CIRC P Closed UR with 1.625"ball. Pumped 8,424.0 8,424.0 08:45 09:30 down w/654 stks and observed ball seat w/1940 psi. Confirmed UR closed with increase in turbine RPM, and increase pump pressure. Took slow pump rates. 3/26/2017 3/26/2017 0.25 INTRM1 CASING OWFF P OWFF,well static. 8,424.0 8,424.0 09:30 09:45 Page 13/27 Report Printed: 4/10/2017 peraf.ns Summary (with Tomelog Depths) -1: '''',c,',.,_"'' >. `-� ; CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/26/2017 3/26/2017 6.75 INTRMI CASING STRP P SOOH f/8,424'to 2,715'MD holding 8,424.0 2,715.0 09:45 16:30 100-170/30 psi out/in slips. Observed tight spots at 7,211',6,274',and 2,971' MD w/25-35k over pull. 3/26/2017 3/26/2017 0.75 INTRM1 CASING CIRC P Circulate a BU at the 9 5/8"casing 2,715.0 2,715.0 16:30 17:15 shoe. 640 gpm,2260 psi,90 rpm, 3.5k TQ. 3/26/2017 3/26/2017 0.50 INTRM1 CASING OWFF P OWFF,well static. B/D lines. 2,715.0 2,715.0 17:15 17:45 3/26/2017 3/26/2017 1.50 INTRM1 CASING SMPD P SOOH f/2,715'to 485'MD holding 2,715.0 485.0 17:45 19:15 30/170 psi in/out of slips. 3/26/2017 3/26/2017 0.25 INTRMI CASING OWFF P OWFF,well static. 485.0 485.0 19:15 19:30 3/26/2017 3/26/2017 0.50 INTRM1 CASING MPDA P Removed RCD bearing and installed 485.0 485.0 19:30 20:00 trip nipple. 3/26/2017 3/26/2017 2.00 INTRM1 CASING BHAH P L/D Intermediate BHA as per SLB. 485.0 0.0 20:00 22:00 3/26/2017 3/26/2017 0.75 INTRM1 CASING RURD 'P Cleaned and cleared rig floor, 0.0 0.0 22:00 22:45 changed elevators,M/U stack washing tool and flushed the stack. 3/26/2017 3/27/2017 1.25 INTRM1 CASING BOPE P Pulled the wear ring and changed out 0.0 0.0 22:45 00:00 upper rams to 7". SimOps,L/D tools from rig floor. 3/27/2017 3/27/2017 1.75 INTRM1 'CASING BOPE P -Tested 7"rams to 250/3800 psi and 0.0 0.0 00:00 01:45 annular to 250/2500 psi. w/7"test joint. R/D test equipment and installed 10.25"ID wear ring. 3/27/2017 3/27/2017 1.25 INTRM1 CASING RURD P R/U Volant tool,bail extensions,7" 0.0 0.0 01:45 03:00 elevators,and 350T Spider Slips. P/U shoe joint and remove bell guide from TD. 3/27/2017 3/27/2017 10.00 INTRM1 CASING PUTB P RIH w/7"26#L80 casing f/surface to 0.0 5,640.0 03:00 13:00 5,640'MD. Checked floats at surface and Bakorloked first 5 jts. 3/27/2017 3/27/2017 1.50 INTRM1 CASING CIRC P Circulated BU as per plan at 5,640' 5,640.0 5,640.0 13:00 14:30 MD w/430 gpm,P/U 175,S/O=140 3/27/2017 3/27/2017 6.25 INTRM1 CASING 'PUTB P RIH W/7"casing f/5,640'to 8,495' 5,640.0 8,495.0 14:30 20:45 MD. 3/27/2017 3/27/2017 0.50 INTRMI CASING HOSO P M/U hanger,landing joint and land 8,495.0 8,530.0 20:45 21:15 casing at 8,530'MD. 3/27/2017 3/27/2017 0.50 INTRM1 CEMENT CIRC P Established circulation at 1 bpm,640 8,530.0 8,530.0 21:15 21:45 psi and reciprocated pipe. 3/27/2017 3/27/2017 0.50 INTRM1 CEMENT RURD P Rigged up cement lines to Volant 8,530.0 8,530.0 21:45 22:15 closed IBOP. 3/27/2017 3/28/2017 1.75 INTRM1 CEMENT CIRC P Circulated and conditioned mud, 8,530.0 8,530.0 22:15 00:00 staging up f/0.5 bbl to 8 bbl at 720 psi. 3/28/2017 3/28/2017 1.25 INTRMI CEMENT CIRC P Continue circulate and condition for 8,530.0 8,530.0 00:00 01:15 cement job @ 8 bpm,720 psi. SIMOPS-Rig down casing elevators, load pipe shed with 3-1/2"tubing.Hold PJSM on cement job. Page 14/27 Report Printed: 4/10/2017 • • Lt Operations Summary (with Timelog Depths) �ry int A f A % ; CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/28/2017 3/28/2017 1.75 INTRM1 CEMENT CMNT P SLB flood and test surface lines to 8,530.0 4,699.0 01:15 03:00 4000 psi-good.Bleed off pressure. SLB pumped 40 bbl 12.5 ppg MudPush II spacer 3.4 bpm 340 psi. Drop bottom(bypass)plug.SLB pumped 49.1 bbl 15.8 ppg Qannik (Yield 1.16 cuft/sx)(238 sks)slurry @ 4 bpm 338-205 psi.Shut down and load top(shutoff)plug,SLB kick out plug with 10.1 bbl water.Rig displace cement with 10.8 ppg LSND @ 8 bpm 470-900 psi FCP for 3000 stks,slow rate to 3 bpm 470 psi and bump plug @ 3111 stks.Pressure up to 970 psi and hold for 5 min.OWFF-Static. Bleed off pressure and check floats- good.Pressure up to 3000 psi and observe stage collar open(4,699' MD).Full returns throughout cement job,landed on hanger no reciprocation. 3/28/2017 3/28/2017 1.00 INTRM1 CEMENT CIRC P Establish circulation through stage 4,699.0 4,699.0 03:00 04:00 collar,stage up from 2-8 bpm, 140- 530 psi,CBU. SIMOPS-PJSM on second stage cement job. 3/28/2017 3/28/2017 1.25 INTRM1 CEMENT CMNT P SLB pumped 30 bbl 11.5 ppg 4,699.0 0.0 04:00 05:15 MudPush II @ 3.6 bpm,220 psi,follow with 44.1 bbl 15.8 ppg Qannik(Yield 1.16 cuft/sx)(214 sks)slurry @ 4.7 bpm,300 psi.Shut down and drop closing plug.SLB kick out plug with 10 bbl water,rig displace with 10.8 ppg LSND @ 8 bpm 330-780 psi,reduce to 3 bpm 540 psi @ 1400 stks,bump plug @ 1697 stks.Pressure up to 2200 psi,observe stage collar shift closed @ 1620 psi.Hold 2200 psi for 3 min per HES,bleed off pressure and OWFF static. 3/28/2017 3/28/2017 2.00 INTRM1 CEMENT RURD P Rig down Volant CRT,lay down 7" 0.0 0.0 05:15 07:15 hand slips and bushings.Blow down top drive,lay down landing joint. 3/28/2017 3/28/2017 1.25 INTRM1 CEMENT WWSP P FMC pull wear ring and set 9-5/8"x 7" 0.0 0.0 07:15 08:30 packoff.RILLDS and test 7"packoff to 5000 psi,witnessed by CPAI. SIMOPS-PJSM-change out saver sub and Auto/Manual IBOP's 3/28/2017 3/28/2017 1.25 INTRM1 CEMENT RURD P Change out upper rams from 7"SBR 0.0 0.0 08:30 09:45 to 3-1/2"x 6"VBR's. SIMOPS-Change out saver sub and IBOP's. 3/28/2017 3/28/2017 3.75 INTRM1 CEMENT RURD P Continue installing saver sub,install 0.0 0.0 09:45 13:30 bell guide and safety wire bolts. 3/28/2017 3/28/2017 0.50 INTRM1 CEMENT SVRG -P Service iron roughneck and 0.0 0.0 13:30 14:00 drawworks. Page 15/27 Report Printed: 4/10/2017 • • L' Operations Summary (with Timelog Depths) CD3-111 Conoc Phillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/28/2017 3/28/2017 1.50 INTRM1 WHDBOP RURD P M/U floor valve,dart valve,P/U 3-1/2" 0.0 0.0 14:00 15:30 test joint and set test plug.R/U and fill lines/stack/manifold for BOPE testing. 3/28/2017 3/28/2017 5.75 INTRM1 WHDBOP BOPE P Test annular to 250/2500 psi,all other 0.0 0.0 15:30 21:15 BOPE to 250/3800 psi w/3%z'&4W TJ.AOGCC Guy Cook waived witness.With 3'/z'TJ test annular 250/2500 psi.Test Upper 3W x 6" VBR's,lower 3W x 6"VBR's,choke valves#1-14,choke needle valve above valve 1,HCR choke and kill, manual choke and kill,4"Demco kill, Auto and manual IBOP,4"XT-39 FOSV and Dart valves to 250-3800 psi.Change to 4W test joint,test annular 250/2500 psi,Test Upper VBR's,Lower VBR's to 250/3800 psi, all tests 5 min ea charted. SIMOPS-Replace stem seals on manual choke. 3/28/2017 3/28/2017 0.25 INTRM1 WHDBOP BOPE P Perform accumulator test,Initial 0.0 0.0 21:15 21:30 system pressure=2975 psi,Pressure after functioning=1475,200 psi attained with electric pump=35 sec, Full system recovery with electric and air pumps=187 sec.4 bottle N2 average=2000 psi. 3/28/2017 3/28/2017 0.50 INTRM1 WHDBOP BOPE P Pull test joint,Test blind rams to 0.0 0.0 21:30 22:00 250/3800 psi,drawdown test manual and super auto choke to 1200 psi. SIMOPS-GIS performed annular flush and freeze protect on CD3-111A. Formation broke over readily @ 790 psi with 2 bbl pumped.Continue 300 bbl water flush,followed by 20 bbl warm diesel from GIS and 40 bbl recovered from de-completion. 3/28/2017 3/28/2017 0.75 INTRM1 WHDBOP RURD P Rig down test equipment,remove test 0.0 0.0 22:00 22:45 plug and set 7"ID wear ring. SIMOPS-blow down choke and kill. 3/28/2017 3/29/2017 1.25 INTRM1 CEMENT BHAH P PJSM,Make up 6-1/8"RSS 0.0 155.0 22:45 00:00 production BHA per DD/MWD to 155' MD 3/29/2017 3/29/2017 1.50 INTRM1 CEMENT PULD P Single in hole from 155'MD to 1,750' 155.0 1,750.0 00:00 01:30 MD with production BHA,picking up 4" 14#Drill Pipe from pipe shed 3/29/2017 3/29/2017 0.50 INTRM1 CEMENT DHEQ P Shallow test MWD,210 gpm, 1310 1,750.0 1,750.0 01:30 02:00 psi.Good test.P/U=85k,S/O=85k 3/29/2017 3/29/2017 2.50 INTRM1 CEMENT PULD P Continue single in hole 1,750'MD to 1,750.0 4,577.0 02:00 04:30 4,577'MD picking up 4"14#drill pipe from pipe shed,fill pipe every 20 stands. 3/29/2017 3/29/2017 0.25 INTRM1 CEMENT REAM P Precautionary wash/ream down from 4,577.0 4,655.0 04:30 04:45 4,577'MD to 4,655'MD @ 200 gpm, 1440 psi,40 rpm,3k Tq.Tag firm cement @ 4,655'MD. P/U=125k,S/0=105k,ROT=115k. Page 16/27 Report Printed: 4/10/2017 • • ,;-.( { o Operations Summary (with Tim& og Depths) rv )- t_� t , CD3-111 ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/29/2017 3/29/2017 1.00 INTRMI CEMENT DRLG P Drill out cement and stage collar from 4,655.0 4,700.0 04:45 05:45 4,655'MD to 4,700'MD with stands from derrick.Tag stage collar on depth @ 4,699',5-10k WOB, 130-200 gpm, 670-1440 psi,40-50 rpm,4-7k Tq. 3/29/2017 3/29/2017 1.00 INTRM1 CEMENT REAM P Wash/ream down from 4,700'MD to 4,700.0 4,955.0 05:45 06:45 4,955'MD out of derrick,200 gpm, 1370 psi,50 rpm,4k Tq.Blow down top drive and OWFF static. 3/29/2017 3/29/2017 0.25 INTRM1 CEMENT TRIP P POOH from 4,955'MD to 4,577'MD 4,955.0 4,577.0 06:45 07:00 racking stands back in derrick. 3/29/2017 3/29/2017 1.25 INTRM1 CEMENT PULD P Continue single in hole 4,577'MD to 4,577.0 5,807.0 07:00 08:15 5,807'MD picking up 4"14#drill pipe from pipe shed,fill pipe every 20 stands. 3/29/2017 3/29/2017 0.50 INTRM1 CEMENT QEVL P P/U stand to 5,705',downlink to 5,807.0 5,807.0 08:15 08:45 Sonicscope 210 gpm,1550 psi. Pumps off.Log down from 5,705'MD to 5,807'MD @ 900 fph to obtain free ring signature. 3/29/2017 3/29/2017 0.75 INTRMI CEMENT PULD P Continue single in hole 5,807'MD to 5,807.0 6,755.0 08:45 09:30 6,755'MD picking up 4"14#drill pipe from pipe shed, 3/29/2017 3/29/2017 2.50 INTRM1 CEMENT QEVL -P Continue singling in hole with 4"DP 6,755.0 7,826.0 09:30 12:00 from shed,6,755'MD to 7,826'MD, logging with Sonicscope @ 900 fph, 3/29/2017 3/29/2017 1.75 INTRM1 CEMENT QEVL -P Continue singling in hole with 4"DP 7,826.0 8,262.0 12:00 13:45 from shed,7,826'MD to 8,262'MD, String took weight @ 8,007'and 8,237',wash and ream @ 200 gpm, 1520-1580 psi,50 rpm,6-6.5k Tq. ' 3/29/2017 3/29/2017 0.50 INTRMI CEMENT RURD P Blow down topdrive and rig up for 8,262.0 8,262.0 13:45 14:15 casing test. 3/29/2017 3/29/2017 0.75 INTRMI CEMENT PRTS P Test casing to 3500 psi for 30 minutes 8,262.0 8,262.0 14:15 15:00 -good,4.1 bbl pumped. SIMOPS-PJSM on cut/slip drilling line. 3/29/2017 3/29/2017 0.25 INTRM1 CEMENT RURD P Blow down lines and rig down test 8,262.0 8,262.0 15:00 15:15 equipment. 3/29/2017 3/29/2017 1.00 INTRM1 CEMENT SLPC P Slip and cut 38'of drilling line, 8,262.0 8,262.0 15:15 16:15 calibrate block height. 3/29/2017 3/29/2017 0.50 INTRM1 CEMENT SVRG P Service top drive and draworks. 8,262.0 8,262.0 16:15 16:45 3/29/2017 3/29/2017 0.75 INTRMI CEMENT COCF P Wash and ream from 8,262'MD to 8,262.0 8,392.0 16:45 17:30 8,392'tag firm cement. 3/29/2017 3/29/2017 2.25 INTRMI CEMENT DRLG P Drill out baffle collar,float collar,shoe 8,392.0 8,540.0 17:30 19:45 track,float shoe on depth and rathole from 8,392'MD to 8,540'MD, 130-200 gpm,930-1720 psi,40-80 rpm,8-11k Tq,5-15k WOB. 3/29/2017 3/29/2017 0.50 INTRM1 CEMENT DDRL P Drill new formation from 8,540'MD to 8,540.0 8,560.0 19:45 20:15 8,560'MD,6,936'TVD,200 gpm 1740 psi,80 rpm, 10.5k Tq.ADT=.35 hrs. 3/29/2017 3/29/2017 0.50 INTRM1 CEMENT CIRC P Circulate and condition for FIT,pump 8,560.0 8,560.0 10:15 20:45 bottoms up @ 200 gpm 1780 psi,80 rpm,8.5k Tq.MW 10.75 ppg in/out. 1/29/2017 3/29/2017 0.50 INTRM1 CEMENT TRIP -P Pump out of hole from 8,560'to 8,420' 8,560.0 8,420.0 !0:45 21:15 MD @ 200 gpm, 1560 psi. Page 17/27 Report Printed: 4/10/2017 '� , Operations Summary (with Tam& og Depths) CD3-111 ConoecaPhil liips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/29/2017 3/29/2017 0.25 INTRM1 CEMENT RURD P Rig up for FIT,OWFF static. 8,420.0 8,420.0 21:15 21:30 3/29/2017 3/29/2017 0.75 INTRM1 CEMENT FIT P Perform FIT to 12.5 ppg EWM, 8,420.0 8,420.0 21:30 22:15 pumped.7 bbl,631 psi with 10.75 ppg mud.Rig down and blow down lines. 3/29/2017 3/29/2017 0.50 PROD1 DRILL 'MPDA P Pull trip nipple and install MPD 8,420.0 8,420.0 22:15 22:45 bearing/elements. 3/29/2017 3/29/2017 0.50 PROD1 DRILL TRIP P RIH from 8,420'MD to 8,560'MD 8,420.0 8,560.0 22:45 23:15 3/29/2017 3/30/2017 0.75 PROD1 DRILL DDRL P Directional drill 8,560'MD to 8,617' 8,560.0 8,617.0 23:15 00:00 MD,6,940'TVD.210 gpm,2070 psi, 80 rpm,11 k Tq.P/U=205k,S/0=135k, ROT=150k.Displace to 10.0 ppg FloThru on the fly.ADT=.88 hrs. OA pressure @ 23:59 hrs=750 psi 3/30/2017 3/30/2017 0.50 PROD1 DRILL DDRL P Directional drill 8,617'MD to 8,642' 8,617.0 8,642.0 00:00 00:30 MD,6,940'TVD.210 gpm,2070 psi, 80 rpm, 11k Tq.P/U=205k,S/0=135k, ROT=150k.Continue displace to 10.0 ppg FloThru on the fly.ADT=.31 hrs. 3/30/2017 3/30/2017 0.25 PROD1 DRILL DISP P Circulate and complete FloThru 8,642.0 8,642.0 00:30 00:45 displacement 200 gpm, 1650 psi, 100 rpm,6.5k Tq.obtain SPR's with 10.0 PPO. 3/30/2017 3/30/2017 0.75 PROD1 DRILL OWFF P Monitor well with MPDE,shut in and 8,642.0 8,642.0 00:45 01:30 build to 186 psi in 35 minutes.(10.52 ppg EMW) 3/30/2017 3/30/2017 5.50 PROD1 DRILL DDRL P Directional drill 8,642'MD to 9,489' 8,642.0 9,489.0 01:30 07:00 MD,6,932'TVD.220 gpm,2015 psi, ECD=11.34 ppg, 150 rpm,Tq on/off= 10k/7k.P/U=172k,S/0=123k, ROT=145k.ADT=4.2 hrs. 3/30/2017 3/30/2017 1.25 PROD1 DRILL OWFF P Monitor well with MPDE and exhale 9,489.0 9,489.0 07:00 08:15 test.Shut in and build to 170 psi in 15 minutes,bleed off 1.5 bbl in 10 minutes.Shut in and build 113 psi in 15 minutes,bleed off 1 bbl in 10 minutes.Shut in and build 74 psi in 15 minutes. 3/30/2017 3/30/2017 3.75 PROD1 DRILL DDRL P Directional drill 9,489'MD to 10,100' 9,489.0 10,100.0 08:15 12:00 MD,6,929'TVD.220 gpm,2090 psi, ECD=11.4 ppg, 130 rpm,Tq on/off= 10.5k/7k.P/U=170k,S/0=123k, ROT=143k.Tour ADT=6.98 hrs. OA pressure=750 psi @ 11:00 hrs 3/30/2017 3/30/2017 2.50 PROD1 DRILL DDRL P Directional drill 10,100'MD to 10,526' 10,100.0 10,526.0 12:00 14:30 MD,6,929'TVD.220 gpm,2090 psi, ECD=11.4 ppg, 130 rpm,Tq on/off= 10.5k/7k.P/U=170k,S/0=123k, ROT=143k.ADT=1.81 hrs. Page 18/27 Report Printed: 4/10/2017 • • , Operations Summary (with Tomelog Depths) CD3-111 ConocoPhil lips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/30/2017 3/30/2017 0.75 PROD1 DRILL OWFF P Formation fingerprint test,shut in and 10,526.0 10,526.0 14:30 15:15 monitor build up to 395 psi in 15 minutes.Bled back 3.5 bbl in 4 minutes.Shut in and monitor build up to 391 psi in 15 minutes. 3/30/2017 3/30/2017 1.25 PROD1 DRILL CIRC P CBU @ 220 gpm,2230 psi,90 rpm, 10,526.0 10,526.0 15:15 16:30 6.5k,taking returns through gas buster.Slight gas cut on bottoms up 8.8 ppg mud balance.Decision to weight up from 10.0 ppg to 10.3 ppg. 3/30/2017 3/30/2017 4.00 PROD1 DRILL CIRC P Circulate,rotate and reciprocate while 10,526.0 10,526.0 16:30 20:30 weight up active system from 10.0 ppg to 10.3 ppg.220 gpm,40-60 rpm,5-6k Tq.Taking returns through gas buster. 3/30/2017 3/30/2017 1.00 PROD1 DRILL OWFF P Formation fingerprint test,shut in and 10,526.0 10,526.0 20:30 21:30 monitor build up to 467 psi in 15 minutes.Bled back 2 bbl in 8 minutes. Shut in and monitor build up to 444 psi in 15 minutes.(Note:No cuttings load I in annulus due weight up) Decision to weight up to 10.5 ppg on the fly,continue monitoring shut in pressures. 3/30/2017 3/31/2017 2.50 PROD1 DRILL DDRL P Directional drill 10,526'MD to 10,860' 10,526.0 10,860.0 21:30 00:00 MD,6,930'TVD.216 gpm,2270 psi, ECD=12.05 ppg, 130 rpm,Tq on/off= 11 k/5.5k.P/U=165k,S/0=125k, ROT=145k.Tour ADT=3.31 hrs. Weight up FloThru mud system from 10.3 ppg to 10.5 ppg on the fly while drilling.Return mud path to flowline (vs Gas Buster)to monitor flow out and gas in returns. OA pressure @ 23:00 hrs=700 psi 3/31/2017 3/31/2017 6.00 PROD1 DRILL DDRL P Directional drill 10,860'MD to 11,6440' 10,860.0 11,644.0 00:00 06:00 MD,6,921'TVD.216 gpm,2270 psi, ECD=12.10 ppg, 130 rpm,Tq on/off= 11k/6k.P/U=172k,S/0=115k, ROT=142k.ADT=3.91 hrs. Weight up FloThru mud system from 10.5 ppg to 10.7 ppg on the fly while drilling due increase in trapped pressure on connections.(504,536 psi) 3/31/2017 3/31/2017 3.25 PROD1 CASING CIRC T Circulate and condition @ 210 gpm, 11,644.0 11,582.0 06:00 09:15 2260 psi,40 rpm,6.5k Tq maintaining 12.2-12.3 ppg ECD with MPDE back pressure.Observe—1-2 ppg gas cut mud in returns.Observe gas cut in returns dissipate after—12.5 ppg ECD. Rack back stand and install FOSV in string.Observe pressure build to 563 psi while racking back stand. Page 19/27 Report Printed: 4/10/2017 ••rations Summary (with Timelo Depths) ) rry 1L.Lo _ CD3-111 ConocoPhiilips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/31/2017 3/31/2017 1.75 PROD1 CASING LOT T Perform dynamic LOT with MPD and 11,582.0 11,582.0 09:15 11:00 PWD.Slowly close choke to apply back pressure monitoring ECD and gain/loss. Initial 12.4 ECD, 150 psi back pressure.Stage up in.1 ppg increments(approx 36 psi)monitoring gain loss.At 13.2 ppg ECD(440 psi) observed leak off to formation @ 20 bph.Relieve back pressure to 12.7 ppg,losses reduced to 4 bph. 3/31/2017 3/31/2017 1.00 PROD1 CASING CIRC T Circulate @ 210 gpm,2340 psi,40 11,582.0 11,582.0 11:00 12:00 rpm,6k Tq.Reciprocate from 11,582' to 11,517'MD.Holding 12.7 ppg EMW with MPDE. Discuss plan forward with drilling team.Determined pressure operating window 12.6 ppg-13.2 ppg. OA pressure @ 12:00 hrs=750 psi 3/31/2017 4/1/2017 12.00 PROD1 CASING WAIT T Circulate @ 210 gpm,2350 psi,40 11,582.0 11,582.0 12:00 00:00 rpm,6k Tq. Reciprocate from 11,582' to 11,517'MD.Holding 12.7 ppg EMW with MPDE. Waiting on 11.4 ppg Flo Pro to be built at Alpine bulk plant for intitial dislplacement,and 12.8 ppg formate brine being built at Deadhorse mud plant for displacement in casing. OA pressure @ 21:30 hrs=675 psi 4/1/2017 4/1/2017 11.00 PROD1 CASING WAIT T Circulate @ 210 gpm,2350 psi,40 11,582.0 11,582.0 00:00 11:00 rpm,6k Tq.Reciprocate from 11,582' to 11,517'MD.Holding 12.7 ppg EMW with MPDE. Waiting on 11.4 ppg Flo Pro to be built at Alpine bulk plant for intitial dislplacement,and 12.8 ppg formate brine being built at Deadhorse mud plant for displacement in casing. 4/1/2017 4/1/2017 1.00 PROD1 CASING DISP P Begin displacement to 11.4 ppg Flo 11,582.0 11,582.0 11:00 12:00 Pro,pump 36 bbl Hi Vis spacer,chase with 11.4 ppg Flo pro @ 210 gpm, 2330 psi,40 rpm,6k Tq. 4/1/2017 4/1/2017 1.00 PROD1 CASING DISP P Continue displacement to 11.4 Flo Pro 11,582.0 11,582.0 12:00 13:00 @ 210 gpm,2380 psi,40 rpm,5k Tq, 12.84 ppg ECD final. 4/1/2017 4/1/2017 1.00 PROD1 CASING OWFF P Perform formation fingerprint @ 11,582.0 11,582.0 13:00 14:00 11,584'MD, 11.4 ppg mud.Shut down and close in chokes,observe max pressure increase of 422 psi in 30 minutes.(12.6 ppg),Bleed off pressure briefly and shut in,pressure build to 413 psi in 5 minutes.Bleed off again and repeat,pressure build to 434 psi flatlined.(12.6 ppg EMW) 4/1/2017 4/1/2017 2.00 PROD1 CASING CIRC P Circulate and observe for gas,max 11,582.0 11,582.0 14:00 16:00 gas at bottoms up 155 units.Establish circulation stage up to 5 bpm,2230 psi,40 rpm,7k Tq,CBU x 2. Page 20/27 Report Printed: 4/10/2017 • • Operations Summary (with Timelog Depths) CD3-111 ConacaPhitl-ips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKE) 4/1/2017 4/2/2017 8.00 PROD1 CASING PMPO P Pump out of hole from 11,582'MD to 11,582.0 9,780.0 16:00 00:00 9,780'MD,maintaining 12.75 ppg ECD with MPD.Making dynamic connections with MPD,holding 540 psi on connections.Pulling speed —500 fph.P/U=165k. OA pressure @ 21:30 hrs=600 psi 4/2/2017 4/2/2017 4.00 PROD1 CASING PMPO P Continue pumping out of hole from 9,780.0 8,830.0 00:00 04:00 9,870'MD to 8,830'MD @ 210 gpm, 2050 psi holding 80 psi annular pressure pulling and 540 psi in slips. Making dynamic connections with MPD. P/U=165k,5/0=122k. 4/2/2017 4/2/2017 1.25 PROD1 CASING PMPO P Pump and lay in 20 bbl HV 11.4 ppg 8,830.0 8,452.0 04:00 05:15 Flo Pro pill.Pump to bit @ 5 bpm, 2020 psi,slow to.8 bpm 870 psi, holding 500 psi annular pressure and pulling 1000 fph laying in 5 bbl per stand from 8,830'MD to 8,452'MD. 4/2/2017 4/2/2017 4.75 PROD1 CASING CIRC P Circulate @ 210 gpm 1960 psi 8,452.0 8,452.0 05:15 10:00 maintaining 12.75 ppg ECD with MPD. Reduce Flo Pro from 11.4 ppg to 11.3 ppg while circulating to facilitate displacement. Prep pit 5 and pill pit with 12.8 ppg Formate brine and HV spacer. 4/2/2017 4/2/2017 1.50 PROD1 CASING PMPO P Pump and lay in 25 bbl HV 12.8 ppg 8,452.0 7,980.0 10:00 11:30 Formate pill.Pump to bit @ 5 bpm, 2020 psi,slow to.8 bpm 870 psi, holding 500-540 psi annular pressure and pulling 1000 fph laying in 5 bbl per stand from 8,452'MD to 7,980'MD. OA pressure @ 11:00 hrs=550 psi 4/2/2017 4/2/2017 2.50 PROD1 CASING DISP P Displace well to 12.8 ppg clear 7,980.0 7,980.0 11:30 14:00 formate brine per schedule 4.4 bpm- lbpm to maintain ECD below 13.2 ppg.No gains or losses.Pumped total 344 bbl for even 12.8 ppg in/out. 4/2/2017 4/2/2017 1.00 PROD1 CASING OWFF P Shut down pumps and close chokes 7,980.0 7,980.0 14:00 15:00 observe 7 psi initial,buid to 14 psi. Open chokes to atmosphere and observe well static for 30 minutes. Blow down top drive. 4/2/2017 4/3/2017 9.00 PROD1 CASING SMPD P Strip out of hole with MPD from 7,980' 7,980.0 2,224.0 15:00 00:00 MD to 2,224'MD holding 75 psi annular pressure at all times to offset potential swab.Observe losses of 1-2 bph in addition to pipe displacement. P/U=165k. OA pressure @ 23:45=420 psi 4/3/2017 4/3/2017 1.50 PROD1 CASING SMPD P Continue strip out with MPD from 2,224.0 997.0 00:00 01:30 2,224'MD to 997'MD holding 75 psi to offset potential swab.Observe losses of 1 bph in addition to pipe displacement. Page 21/27 Report Printed: 4/10/2017 •ratio s Summary (with Timelog D�hs) - CD3-111 ConocoPhifliips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/3/2017 4/3/2017 0.25 PROD1 CASING OWFF P Observe well for flow prior to pulling 997.0 997.0 01:30 01:45 MPD,static for 15 minutes. PJSM on pulling MPD and install trip nipple. 4/3/2017 4/3/2017 0.50 PROD1 CASING `MPDA P Pull MPD element and strip off pipe, 997.0 997.0 01:45 02:15 install trip nipple.Leak check and OWFF static slight drop. 4/3/2017 4/3/2017 1.50 PROD1 CASING TRIP P POOH on elevators from 997'MD to 997.0 162.0 02:15 03:45 162'MD.Lay down 2 stands HWDP and jars. 4/3/2017 4/3/2017 1.25 PROD1 CASING BHAH P Lay down BHA per DD/MWD reps. 162.0 0.0 03:45 05:00 Clean and clear rig floors of BHA components and MPD element. Total trip from shoe,Calc fill=46.18 bbl,Actual Fill=55 bbl. 4/3/2017 4/3/2017 2.00 COMPZN CASING RURD P Rig up double stack power tongs,4W 0.0 0.0 05:00 07:00 tubing elevators,air slips...Rig up fillup line. SIMOPS-Inspect top drive,Verify pipe and jewelry count and placement, PJSM on running liner. 4/3/2017 4/3/2017 5.00 COMPZN CASING PUTB P P/U and RIH with 4W TXP frac liner 0.0 2,141.0 07:00 12:00 per detail to 2,141'MD Fill pipe every 10 jts,50 jts in hole.P/U=75k. 4/3/2017 4/3/2017 3.00 COMPZN CASING PUTB P Continue P/U and run 4W TXP frac 2,141.0 3,444.0 12:00 15:00 liner per detail from 2,141'MD to 3,444'MD,82 jts total.S/0=90k. 4/3/2017 4/3/2017 1.00 COMPZN CASING OTHR P M/U liner hanger assembly as per 3,444.0 3,476.0 15:00 16:00 Baker,XO to XT39 DP connection. SIMOPS-R/D casing equipment. 4/3/2017 4/3/2017 0.50 COMPZN CASING RUNL P RIH with liner on 4"DP to 3,585'MD. 3,476.0 3,585.0 16:00 16:30 4/3/2017 4/3/2017 0.50 COMPZN CASING CIRC P R/U head pin and establish circulation. 3,585.0 3,585.0 16:30 17:00 Stage pump to 2 bpm, 140 psi. Circulate liner volume. 4/3/2017 4/4/2017 7.00 COMPZN CASING RUNL 'P -Continue running liner on 4"DP @ 3,585.0 17:00 00:00 1000 fph from 3,585'MD to 8,063' MD.Fill pipe every 10 stands. S/0=125k. OA pressure @ 22:00 hrs=400 psi 4/4/2017 4/4/2017 0.75 COMPZN CASING RUNL P Continue RIH with 4W TXP Frac liner 8,063.0 8,490.0 00:00 00:45 assembly on 4"DP from 8,063'MD to 8,490'MD. 4/4/2017 4/4/2017 0.25 COMPZN CASING OWFF P Observe well for flow,static.PJSM on 8,490.0 8,490.0 00:45 01:00 pulling trip nipple and install MPD bearing. 4/4/2017 4/4/2017 0.50 COMPZN CASING MPDA P Pull trip nipple and install MPD 8,490.0 8,490.0 01:00 01:30 bearing/element.Install 4"FOSV with 5'pup on top of string. 4/4/2017 4/4/2017 0.50 COMPZN CASING SFTY P PJSM on displacing well from 12.8 8,490.0 8,490.0 01:30 02:00 ppg brine to 11.4 ppg Flo Pro, applying back pressure and monitoring returns. Page 22/27 Report Printed: 4/10/2017 • • 1 ' Operations Summary (with T mek g Depths) CD3-111 Kr.: ConocoPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/4/2017 4/4/2017 4.00 COMPZN CASING DISP P Stage pumps up from.5 bpm to 2 8,490.0 8,490.0 02:00 06:00 bpm,210 psi observe no losses. Pump 15 bbl HV Flo Pro spacer, follow with 330 bbl 11.4 ppg Flo Pro. Pump 11.4 ppg to shoe @ 810 psi FCP.Maintain 800-830 psi string pressure via closing MPD choke as 11.4 comes up annulus.FCP's 830 psi with 340 psi annular back pressure. Ramp down to dynamic connection @ 505 psi AP.Close FOSV,break top drive connection and slowly open FOSV to check that floats are holding, good.Blow down top drive,RID FOSV with 5'pup. P/U=165k,S/0=125k @ 8,490'MD. 4/4/2017 4/4/2017 6.00 COMPZN CASING RUNL P Continue running liner on drill pipe into 8,490.0 10,981.0 06:00 12:00 open hole from 8,490'MD to 10,981' MD,stripping in with MPD holding 505 annular back pressure.Stage running speed from 250 fph to 700 fph monitoring displacement,—1 bph losses.5/0=112k @ 10,981'MD. 4/4/2017 4/4/2017 2.00 COMPZN CASING RUNL P Continue running liner on drill pipe 10,981.0 11,604.0 12:00 14:00 from 10,981'MD to 11,604'MD, stripping in with MPD holding 505 annular back pressure.500 fph monitoring displacement,—1 bph losses.P/U=190k,S/0=105k. 4/4/2017 4/4/2017 2.50 COMPZN CASING CIRC P M/U FOSV and single,put liner 11,604.0 11,605.0 14:00 16:30 hanger 1 packer on depth.Establish circulation @.5 bpm,850 psi with 420 psi back pressure.Stage rates up to 2 bpm,1280 psi with 320 psi back pressure.Circulate and condition, CBU observe no gas on returns,some heavy mud 11.7 ppg.FCP=970 psi, 320 psi AP. 4/4/2017 4/4/2017 2.00 COMPZN CASING PACK P Break single,drop 1.25"WIV ball, 11,605.0 8,154.0 16:30 18:30 pump down @ 2 bpm,980 psi.Ball on seat @ 1178 stks.Set liner hanger with 2600 psi(320 psi AP).Slack off to 60k,hanger set.P/U to neutral, pressure up to 3500 psi,bleed off pressure.Pressure up to 4000 psi and hold 2 min,bleed off pressure.Bleed off 320 psi annular back pressure. Close chokes and observe no pressure build.Slack off to 60k, pressure up and observe shear @ 3400 psi,bleed off pressure.P/U 175k,pull up 6'to expose dog sub, rotate 20 rpm 5k,set down 40k. Running tool free,pick up to neutral weight.Lay down single and FOSV. Liner set @ 11,609'MD,TOL @ 8,131.45'MD. 1/4/2017 4/4/2017 1.00 COMPZN l CASING PRTS P Rig up and pressure test casing 8,154.0 8,154.0 18:30 19:30 annulus and packer to 3000 psi for 15 minutes charted.2.3 bbl pumped to pressure up. Page 23/27 Report Printed: 4/10/2017 n Operations Summary (with Timelo Depths) 1,,1 r�vr-L, k - ' CD3-111 C©nocoPhitliphs X Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 4/4/2017 4/4/2017 0.50 COMPZN WELLPR PULD P Pull running tool clear from liner top, 8,154.0 8,092.0 19:30 20:00 lay down 2 singles.Blow down testing lines. 4/4/2017 4/4/2017 0.50 COMPZN WELLPR OWFF P Flow check well for 30 minutes static 8,092.0 8,092.0 20:00 20:30 with 11.4 ppg Flo Pro. 4/4/2017 4/4/2017 1.50 COMPZN WELLPR DISP P PJSM,displace well over to 9.8 ppg 8,092.0 8,092.0 20:30 22:00 brine @ 5 bpm, ICP=1210 psi, FCP=520 psi,62%flow out.Pumped total 340 bbl.Blow down top drive. 4/4/2017 4/4/2017 1.50 COMPZN WELLPR OWFF P Line up MPD to cellar and monitor well 8,092.0 8,092.0 22:00 23:30 appeared out of balance.Slight trickle, reducing for(.3 gpm to<.1 gpm)1 hour,observe until static 30 min. SIMOPS-Prep and PJSM for removing MPD. 4/4/2017 4/5/2017 0.50 COMPZN WELLPR MPDA P Remove MPD bearing/element,install 8,092.0 8,092.0 23:30 00:00 trip nipple.Fill and leak check. Observe well again static. OA pressure @ 22:00 hrs=385 psi 4/5/2017 4/5/2017 0.25 COMPZN WELLPR OWFF P Observe well for flow after install 8,092.0 8,092.0 00:00 00:15 MPD.Fill trip nipple with hole fill,shut off and observe well static for 15 minutes. 4/5/2017 4/5/2017 7.50 COMPZN WELLPR PULD P POOH laying down 4"DP from 8,080' 8,092.0 0.0 00:15 07:45 MD.Shut down hole fill and flow check static @ 4,300'and 152'.Function rams.Calc Fill=45.9 bbl,Actual Fill=46 bbl. 4/5/2017 4/5/2017 0.75 COMPZN WELLPR 'BHAH P Lay down Baker liner running tools, 0.0 0.0 07:45 08:30 clean and clear rig floor. SIMOPS-FMC pull 7.0625"ID wear ring and install 9"ID retrievable wear ring. 4/5/2017 4/5/2017 3.25 COMPZN RPCOMP RURD P R/U to run completion,P/U Grippy 0.0 0.0 08:30 11:45 clamp crates,P/U I-Wire and SSSV spools/sheaves,hang sheaves and run lines through.P/U and R/U double stack power tongs,air slips,hand tools and equipment for tubing run. 4/5/2017 4/5/2017 0.25 COMPZN RPCOMP 'SFTY P Verify pipe and jewelry counts,PJSM 0.0 0.0 11:45 12:00 on running completion with CPAI,DDI crew,DDI casing,PTS, Baker completion&SLB. 4/5/2017 4/5/2017 1.50 COMPZN RPCOMP PUTB P P/U WLEG locator assy,3W EUE 0.0 181.0 12:00 13:30 8rdmod tubing,2.813 XN nipple w/ RHC plug 2.75 no-go,Baker Premier Packer to 181'MD.Break out collar on 2'pup for gauge carrier. 4/5/2017 4/5/2017 1.00 COMPZN RPCOMP PUTB P M/U PTS gauge carrier to lower 2'pup 181.0 181.0 13:30 14:30 and Baker Lock.Remove gauge carrier upper pup,replace with 4'pup and Baker Lock. 4/5/2017 4/5/2017 1.50 COMPZN RPCOMP PUTB P Terminate I-Wire to gauge and test 181.0 181.0 14:30 16:00 per PTS,CPAI witness. Page 24/27 Report Printed: 4/10/2017 • • Op rations Summary (with Tomelog !0epths) CD3-111 ConcaccaPhillips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 14/5/2017 4/6/2017 8.00 COMPZN RPCOMP PUTB P Continue P/U and run 3'/z'upper 181.0 4,959.0 16:00 00:00 completion from 181'MD to 4,959' MD,(154 jts total,2.813 X nipple, GLM w/SOV 2500 psi,2 GLM with dummy.)Clamping with PTS Grippy clamp every collar.I-Wire under constant test while running. S/0=92k.OA pressure @ 22:00 hrs= 400 psi 4/6/2017 4/6/2017 1.50 COMPZN RPCOMP PUTB P Continue P/U and run 3W EUE-8rdM 4,959.0 5,980.0 00:00 01:30 completion from 4,959'MD to 5,980' MD per detail,installing PTS Grippy clamp on every collar. 4/6/2017 4/6/2017 0.50 COMPZN RPCOMP SSSV P Make up SLB Camco TRMAXX-5 5,980.0 6,010.0 01:30 02:00 SSSV,instal and pressure test control line 5200 psi 10 minutes good.Instal clamps above and below SSSV. 4/6/2017 4/6/2017 3.50 COMPZN RPCOMP PUTB P Continue P/U and run 3W EUE-8rdM 6,010.0 8,062.0 02:00 05:30 completion from 6,010'MD to 8,062' MD per detail,installing PTS Grippy clamp over both I Wire and SSV control line on every collar. 4/6/2017 4/6/2017 0.50 COMPZN RPCOMP PUTB P RIH with jts 254,255 and 25'in on 8,062.0 8,152.0 05:30 06:00 256,tag TOL @ 8151',set down 8k and shear locator sub screws. Continue in and fully locate 26'in on jt #256 @ 8,152.34'MD with 10k,P/U and repeat to verify.P/U=126k, S/0=105k. 4/6/2017 4/6/2017 0.25 COMPZN RPCOMP PULD P Lay down jts 256,255 and 254 to 8,152.0 8,062.0 06:00 06:15 8,062'MD. 4/6/2017 4/6/2017 1.00 COMPZN RPCOMP HOSO P M/U FMC wear ring puller and retrieve 8,062.0 8,072.0 06:15 07:15 9"ID wear ring.M/U 8.1'space out pup and 4W TXP x 3W EUE XO to 8,072'. 4/6/2017 4/6/2017 2.00 COMPZN RPCOMP THGR P Make up 4%"TXP joint and hanger. 8,072.0 8,117.0 07:15 09:15 Orient hanger production port.SLB/ PTS/FMC terminate I-Wire and SSSV control line through hanger. Test Swedge lock connections to 5000 psi,good.Ensure SSSV is open. SIMOPS-Prep for spotting CI brine, R/D double stack tongs,OWFF for 30 minutes static. 4/6/2017 4/6/2017 1.75 COMPZN RPCOMP CRIH P RIH to 8,145'MD.R/U and pump 23.5 8,117.0 8,117.0 09:15 11:00 bbl 9.8 ppg corrosion inhibited brine, displace with 66 bbl 9.8 ppg neat brine @ 2-2.4 bpm, 160-230 psi.Shut down, drain stack,blow down choke and kill lines. SIMOPS-Lay down clamp crates via Beaverslide. 4/6/2017 4/6/2017 0.50 COMPZN RPCOMP HOSO P RIH and land hanger @ 8,148.97'MD, 8,117.0 8,149.0 11:00 11:30 (3.37'off fully located)FMC RILDS. Final P/U=125k,S/0=100k.Total clamps in hole=258 ea-3W Full clamps,3 ea-4W single clamps,2 ea -SS bands. SIMOPS-R/D I-Wire and SSSV line sheaves.Prep pressure testing equipment. Page 25/27 Report Printed: 4/10/2017 moi Operations Summary (with Tirnelog Depths) CD3-111 ConoeoPhiilips Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/6/2017 4/6/2017 1.00 COMPZN RPCOMP THGR P R/U and pressure test hanger seals to 8,149.0 8,149.0 11:30 12:30 250/5000 psi 10 minutes each with test pump and chart recorder. 4/6/2017 4/6/2017 1.00 COMPZN RPCOMP RURD P Rig up surface lines to set and test 8,149.0 8,149.0 12:30 13:30 packer.Pressure test lines to 4100 psi,good. 4/6/2017 4/6/2017 2.50 COMPZN RPCOMP PACK P Set and test packer.Pressure up 8,149.0 8,149.0 13:30 16:00 down tubing observe shear @ 2,450 and 3,450 psi,continue pressure up to 4100 psi chart for 30 min(tubing test). Bleed pressure to 1500 psi,pressure up on annulus to 3000 psi for 30 minutes charted.Observe OA pressure increase from 400-500 psi. Bleed IA then tubing,with tubing open pressure up down IA,observe SOV shear out @ 2750 psi.Pump 1.5 bpm 990 psi through SOV.Shut down and pump down tubing 1.5 bpm 570 psi for 3 bbl. 4/6/2017 4/6/2017 0.25 COMPZN WHDBOP RURD P Blow down rig down lines,lay down 8,149.0 0.0 16:00 16:15 landing joint A. 4/6/2017 4/6/2017 0.75 COMPZN WHDBOP MPSP P FMC set HP-BPV,R/U landing joint B 0.0 0.0 16:15 17:00 and test HP-BPV to 2500 psi for 15 minutes charted. Verify barriers. 4/6/2017 4/6/2017 0.50 COMPZN WHDBOP RURD P Blow down rig down lines,lay down 0.0 0.0 17:00 17:30 landing joint B. 4/6/2017 4/6/2017 3.00 COMPZN WHDBOP GLEN P Lay down PTS and SLB completion 0.0 0.0 17:30 20:30 equipment from rig floor.Clean under pipe racks,rotary table,drip pan and flow box. 4/6/2017 4/6/2017 0.50 COMPZN WHDBOP WWWH P P/U stack washer,flush BOP stack 0.0 0.0 20:30 21:00 and flowline @ 430 gpm, 100 psi,10 rpm 4/6/2017 4/6/2017 1.00 COMPZN WHDBOP MPDA P R/D MPD equipment,valves,hoses, 0.0 0.0 21:00 22:00 Orbit valve,flow box. 4/6/2017 4/6/2017 1.75 COMPZN WHDBOP NUND P N/D BOPE from wellhead and set on 0.0 0.0 22:00 23:45 stump. OA pressure @ 22:00 hrs=400 psi 4/6/2017 4/7/2017 0.25 COMPZN WHDBOP NUND P FMC/SLB/PTS prep to terminate I 0.0 0.0 23:45 00:00 wire and SSSV control line through wellhead. 4/7/2017 4/7/2017 2.25 COMPZN WHDBOP NUND P PTS Terminate and test I-wire 0.0 0.0 00:00 02:15 penetration out wellhead. SIMOPS-Prep test equipment, disconnect choke/flare lines outside for rig move.Drain both mud pumps and remove valves,springs and caps for pad move.Install mouse hole,rig down mud line in mezzanine,remove drain plugs from pumps in centrifugal room. 4/7/2017 4/7/2017 1.25 COMPZN WHDBOP NUND P N/U tree per FMC,pressure test 0.0 0.0 02:15 03:30 adapter flange void and I-Wire/SSSV penetrations to 5000 psi for 10 minutes CPAI witnessed.R/D test equipment.SSSV pumped up to 5000 psi in open position. 4/7/2017 4/7/2017 1.50 COMPZN WHDBOP PRTS P R/U and test tree to 250/5000 psi, 10 0.0 0.0 03:30 05:00 minutes each charted.Rig down test equipment. Page 26/27 Report Printed: 4/10/2017 • ., , rat.ns Summary (with Timelog Dep hs) ` ,,,,-,, ,4CD3-111 ConocoPhil hps Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/7/2017 4/7/2017 0.50 COMPZN WHDBOP MPSP P FMC pull HP-HPV. 0.0 0.0 05:00 05:30 4/7/2017 4/7/2017 0.25 COMPZN WHDBOP RURD P Rig up lines to freeze protect well with 0.0 0.0 05:30 05:45 GIS. 4/7/2017 4/7/2017 1.50 COMPZN WHDBOP FRZP P PJSM on freeze protect.Ball Mill 0.0 0.0 05:45 07:15 pressure test lines to 2500 psi.Pump total 75 bbl diesel down IA(20 bbl heated diesel from GIS,34 bbl recycled LEPD,follow with 21 bbl heated diesel)taking returns out tubing. SIMOPS-BWM on BOPE 4/7/2017 4/7/2017 0.50 COMPZN 'WHDBOP FRZP P Line up tubing and IA and U-tube 0.0 0.0 07:15 07:45 diesel for 30 minutes,200 psi on tubing and IA. SIMOPS-BWM on BOPE 4/7/2017 4/7/2017 0.25 COMPZN WHDBOP RURD P Rig down freeze protect lines. 0.0 0.0 07:45 08:00 4/7/2017 4/7/2017 1.50 COMPZN WHDBOP MPSP P FMC rig up lubricator and test to 2700 0.0 0.0 08:00 09:30 psi.Set BPV and lay down lubricator. 4/7/2017 4/7/2017 1.00 COMPZN WHDBOP PRTS P Pressure test BPV in direction of flow 0.0 0.0 09:30 10:30 to 2500 psi charted,via IA with GIS pump.Blow down lines and squeeze manifold,rig down. 4/7/2017 4/7/2017 1.50 DEMOB MOVE RURD P Secure well,rig down double annulus 0.0 0.0 10:30 12:00 valves,install flanges and gauges.Rig down working platform on tree.Lay down lubricator from rig floor,prep to lay down 4"DP. Tubing=250 psi, IA=250 psi,OA= 400 psi Final readings on downhole gauge, 3493 psi,70°C,45.59 V. 4/7/2017 4/7/2017 10.50 DEMOB MOVE PULD P Lay down 97 stands 4"DP via 0.0 0.0 12:00 22:30 mousehole. SIMOPS-Prep rig modules for separation,blow down water lines, check tires,clean up ancilliary materials,secure roof items,clear snow/prep rig mats. Off HiLine @ 17:30 hrs. 4/7/2017 4/8/2017 1.50'DEMOB MOVE RURD P Lay down mousehole,continue prep 0.0 0.0 22:30 00:00 for separating modules,blow down steam,swap electrical to cold starts. Trucks on location @ midnight.Rig release @ 00:00 hrs 4/8/17. Page 27/27 Report Printed: 4/10/2017 • • CD3-111 DTTMST JOBTYF SUMMARYOPS 3/11/17 DRILLIN Move and stage rig support modules @ CD2 ice pad, move Sub structure 13.9 miles up to CD2 ice road ramp (Mile 15.9). Support mod maintenance, Prep well CD3-111A, lay rig mats @ Tamayayak bridge. Notify AOGCC of upcoming test. 3/12/17 DRILLIN Continue moving Sub to CD3, spot/center sub over well. SIMOPS- Move support modules to CD3. Make up pit and motor complexes. 3/13/17 DRILLIN Continue R/U on CD3-111A, make up GIS, pipe shed. Accept rig @ 06:00 hrs. Rig up choke skid, hardlines and tank. Pull BPV, PT lines, circ out freeze protect. FC, install HP-BPV and test. N/D tree, N/U BOPE and MPDE. 3/14/17 DRILLIN Test MPDE, test BOPE to 250/3800 psi (AOGCC Waived witness.) Pull blanking plug and BPV, R/U and pull and L/D 3'/2'tubing from 3,115' MD. Installed wear ring. 3/15/17 DRILLIN RIH w/Bridge Plug assy and set at 3,088' MD. Slip &cut, serviced rig. POOH to surface and M/U 7" Csg cutting assy. RIH tagged CIBP, spaced out, and cut 7" Csg @ 2,921' MD. Attempted to circulate OA with no success. Circulated BU, OWFF w/slight flow. Weighted up to 10.3 ppg and OWFF again w/slight flow. Repeated several times working MW up in 0.5 ppg increments to 11.3 ppg, still observing slight flow. 3/16/17 DRILLIN Weighted mud up to KW of 12 ppg. POOH to next cut depth @ 2,686' MD and cut 7" csg. Observed 720 psi pressure build on OA to confirm cut. Circulated BU and displaced OA to 12 ppg mud. POOH with the cutting assy. Installed and tested 7" SBR. Pulled 7" pack off. M/U 7" spear and pulled hanger to surface. Circulated the OA. Removed spear and L/D. 3/17/17 DRILLIN Pulled 1st casing section to surface, L/D 62 jts, 2,921' of 7" casing. Changed rams to 3 1/2"x6"and tested. RIH w/casing spear assy and engaged 2nd casing segment at 2,921' MD. Attempted to pull casing with no success. Could not release from 7" casing and required the use of surface jars to break free. Tool came free after firing surface jars. 3/18/17 DRILLIN POOH w/spear assy and M/U 7" casing cutter. RIH and cut csg at 2,822' MD. Circulated BU and POOH. M/U spear assy and engage 7"casing at 2,608' MD. Attempted to jar free with no success. Could not release from 7" casing and M/U surface jars to break free. POOH w/spear assy and M/U 3/19/17 DRILLIN Cut 7" casing at 2,739' and 2,782' MD. POOH. M/U spear assy and pulled the 1st 56' section to surface and L/D. Ran back in and retrieved the 2nd 43' long section to surface and L/D. M/U spear assy and started RIH to retrieve the 3rd section. 3/20/17 DRILLIN Engaged the 7" casing fish at 2,789' MD and POOH. L/D 43.3' 7"casing section. M/U 30 jts of 3 1/2" tubing for cmt stinger and RIH to 3,088' MD. Placed KOP w/43.3 bbl of 17 ppg cmt(TOC @ 2,521' MD). Pulled out of cmt plug and circulated well clean. POOH with the cmt stinger and R/U to test BOPE. 3/21/17 DRILLIN L/D Tubing running tools. Tested BOPE. M/U 29 stands of 4" 14# DP and racked back. M/U 8 3/4" motor assy and singled in hole. Tagged hard cmt @ 2,519' MD and drilled out. Kicked off of cmt plug and drilled to 2,777' MD, 2560' TVD. WNS "VD CD3-111 ConocoPhillips 4 Well Attribut Max Angle TD Al 1,kt:.I"1„ Wellbore API/UWI Field Name Wellbore Status Inc'(°) MD(ftKB) Act Btm(ftKB) Crap co 9ltl6ps"' 501032052600 FIORD NECHELIK PROD 93.85 10,073.20 15,073.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-111,5/9/20178.22.29 AM SSSV:TRMAXX-5E Last WO- 42.61 3/25/2006 Vertical schemabc.(actuag Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag- Rev Reason-PLUG BACK pproven 5/5/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread isziPRODUCTION 7 6.276 34.2 8,660.0 6,932.2 26.00 L-80 BTCM HANGER,31.0 Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1 WINDOW 61/2 5.000 14,181.0 14,191.0 6,872.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L j;( OPEN HOLE 61/8 8,660.0 15,073.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 31.2 8,159.81 6,788.1 9.30 L-80 8RD EUE Mod • Completion Details 1ji Nominal ID 11 1 I ) lop(ftKB) lop(TVD)(ftKB) Top Incl(°) em Des Com n) 31.2 31.2 0.00 HANGER FMC HANGER W/2.23 PUP 3.958 114.8 114.8 0.50 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 I 2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 4/26/2010 2.812 8,016.9 6,721.3 60.35 SLEEVE BAKER CMD SLIDING SLEEVE 2.813 I 8,100.9' 6,761.7 62.43 PACKER BAKER PREMIER PACKER 2.875 8,147.9 6,782.9 63.87 NIPPLE HOWCO'XN'NO GO NIPPLE 2./50 CONDUCTOR;38.D-714.0-4 8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 3,088.0 2,772.1 33.77 CIBP 7"Cast Iron Bridge Plug for Kick Off Cmt. 3/15/2017 0.000 Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(lb) Date 4/4/2013 Stimulations&Treatments Vol Clean Pump Stg 0 Top(ftKB) Btm(ftKB) Dale StimRreat Fluid (bbl) Vol Slurry(bbl) 1 8,660.0 15,073.0 4/4/2013 Proppant Designed(lb) Proppant In Formation(Ib) Date A 100,000.0 102,000.0 4/13/2017 SAFETY VLV;2,150.0 rF. za Cement Squeezes ISO SLEEVE;2,150.0 Tubing;2,154.3 Top(ftKB) Min(ftKB) Top(TVD) Bt(88KB D) Des Start Date Com 2,521.0 3,088.0 2,303.1 2,772.1 Cement 3/4/2017 Squeeze 7,000.0 7,928.0 6,011.5 6,675.9 Cement 3/4/2017 Squeeze Mandrel Inserts St ati SURFACE;36.3-2,721.0 N Top(TVD) Valve Latch Port Size TRO Run INTERMEDIATE;34.1-8,530.0 Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 3,846.7 3,403.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,676.0 4/5/2013 2 6,492.3 5,593.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 Cement Squeeze,2,5210fKB 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4,2013 CIBP;3,088.0 lir- Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111 8 CD3-111L1 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,3,848.7 GAS LIFT,6.4923 •Ib # s .. A Cement Squeeze,7,000 0 ftKB ` GAS LIFT:7,9288 It SLEEVE,8016.9 f PACKER,5100.5 NIPPLE;8,147 9 WLEG,8,159.3 PRODUCTION,2,820.0-8,660.0 FRAC;8,680.0 #*f# L1 WINDOW,14,181.0-14,191.0 4%.*.at'k I OPEN HOLE;8,860.0-15,073.0 n•a l % WNS �D �D3-111 L1 ConocoPhiDDips Well Attribute Max Angle TD Alaska.Inc WellboreAPI/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) Con .171Mips 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 ... M Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CO3-111L1,5/9/2017 a:21:58 AM SSSV'TRMAXX-5E Last WO: 42.61 3/25/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:PLUG BACK jennalt 5/5/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtiLen(I...Grade Top Thread im' L1 OPEN HOLE 6 1/8 14,190.0 16,645.0 6,855.3 HANGER; .11.16-37411 I Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date ititL Vis., 4/4/2013 Proppant Designed(Ib) Proppant In Formation(Ib) Date 100,000.0 102,000.0 4/13/2017 f' Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL CD3-111 8 CD3-111L1 I1I s li: 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 If I CONDUCTOR,36.0-1140 SAFETY VLV;2,150.0 -:�� ISO SLEEVE,2,150.0 # Tubing;2,154.3 it SURFAC;34.36.3-21 A,,21530.0.01 INTERMEDIATE Cement Squeeze,2,521.0 8KB CIBP,3,088.0 -- I NE GAS LIFT;3,846.7 it I GAS LIFT,6,492.3 - V Cement Squeeze,7000.0 ftKB GAS LIFT 7,928.8 SLEEVE;8,016.9 PACKER;8,100.9 NIPPLE;8,147.9 II; WLEG,8,159.3IA PRODUCTION;2,820.0-8,660 0— FRAC;8,660.0 '' OPEN HOLE;8,660.0-15,073.0 I I'`'. 1 L1 WINDOW,14,181.0.14,191.0' •••. L1 OPEN HOLE;14,190.0- s 16,645.0 1✓OF 7 sr- //j��s THE STATE Alaska Oil and Gas o fccConservation Commission LAV 333 West Seventh Avenue r. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA 1(j` Fax: 907.276.7542 www.aogcc.alaska.gov Marshall Brown SCANNED MAR 1 7 2017, Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CRU CD3-111L1 Permit to Drill Number: 206-042 Sundry Number: 317-035 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this LI day of February,2017. RBDMS 0U FEB 2 7 2017 RECEIVED STATE OF ALASKA JAN 2 4 017 ALASKA OIL AND GAS CONSERVATION COMMISSION 07"$ 22` ` APPLICATION FOR SUNDRY APPROVALS AOG 7 20 AAC 25.280 1.Type of Request: Abandon f Plug Perforations E Fracture Stimulate Repair Well r Operations Shutdown r Suspend I Perforate E Other Stimulate E Pull Tubing E Change Approved Program fl Plug for Redrill 17 Perforate New Pool r Re-enter Susp Well r Alter Casing E Other: 2.Operator Name: 4.Current Well Class: TR, 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory I Development S[` 206-042 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20526-60 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes r No RA / CRU CD3-111L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,ADL 364471,ADL 364470' Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 16,645' 6,855' 16645 6855 3$ 1 si If r 1-- NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2,685' 9 5/8 2,721' 2,469' Production 8,626' 7" 8,660' 6,932' Open Hole 2,455' 6 1/8 16,645' 6,855' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): open Hole 3.500" L-80 8,160' 14190-16645 ' 6873-6855 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER MD=8101 TVD=6762 SSSV:CAMCO TRMAXX-5E-LOCKED OUT 4/25/2010 MD=2130 TVD=1994 12.Attachments: Proposal Summary 0 Wellbore schematic jj 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic E Development v F Service I- 14.Estimated Date for 2/13/2017 15.Well Status after proposed work: jib Commencing Operations: OIL E WINJ r WDSPL fl Suspended l' 16.Verbal Approval: Date: GAS E WAG GSTOR I- SPLUG I— Commission Representative: GINJ E Op Shutdown I- Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Marshall Brown @ 265-6218 Email H.Marshall.Brown(a?conocoohillips Printed Name Marsha Brown Title Wells Engineer Alf4t4ACVikte— Vz 3/Z0/ Signature Phone 265-6218 (Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _O SS / Plug Integrity Q BOP Test NatMechanical Integrity Test ❑ Location Clearance ❑ .�.��j' �!�' 14L‘ L‘I Other: UOP t-r 5 l- to 3 8 G o PS-I-5 - / vtn �Lar pre V' I ' 14-rr t--/-5tp ZJ'' O Post Initial Injection MIT Req'd? Yes ❑ No ( i'7 "4RBDMS 0 FEB 2 7 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: j® -- 0 APPROVED BY Approved� by: �1 / D A COMMISSIONER THE COMMISSION Date: Z/Zl/ 17 10- O '` i at L Submit Form and Form 10-403 Revised 11/2015 ppp11}AWW{I p Isat� valid for 12 months from the date of approval. Attachments in Duplicate WNS CD3-111 Plug for Sidetrack Sundry Summary of Operations: The CD3-111 annualized oil production rate has decreased from a peak of 4,548 BOPD in 2008 to 313 BOPD in 2016 due to a combination normal decline,scale buildup,and hole collapse after 2013 open- hole fracture stimulation.The CD3-111A will be completed with a multistage frac port liner to restore productivity and improve resource recovery from the pattern. CD3-111 current open hole lateral needs to be squeezed off with cement and abandoned. Prior to sidetrack,the current open hole laterals CD3-111 &CD3-111L1 will be squeezed with 50bbl. of 15.8 ppg class G cement below a cement retainer set in the tubing tail @ +/-8,130 ft.An additional 35 bbl. of 15.8 ppg class G cement will be laid in above the cement retainer and squeeze thrr the gas lift mandrel @ 7,928 ft. leaving a +/-1,000 ft. cement plug in the wellbore. Estimated TOC is+/-7,150ft. Following the cement squeeze, a tubing cut will be performed at 3,115 ft., 394 ft. below the surface casing shoe.And a BPV will be left in the well. Using the formation pressure data form the area,the maximum potential surface pressure,assuming a gas gradient of 0.1 psi/ft. would be 3,461 psi. Pre-Rig Work: 1. RU Slickline: Dummy off GLM stations 1&2 and pull valve from station 3. Circulate well full of fluid. 2. RU Coiled tubing: RIH and set cement retainer @ 8,130 ft. pump 50 bbl. 15.8 ppg class G cement and squeeze off open hole lateral. Unsting from cement retainer and lay in 35 bbl. of 15.8 ppg class G cement. 3. RU slickline:Tag top of cement and pressure test cement plug, circulate well full of 9.8 ppg brine thru station 2 gas lift mandrel. Set dummy valve in station 2 gas lift mandrel. 4. RU E-line: RIH and cut tubing @ 3,115 ft. 5. Prep site for rig arrival and set BPV Rig-Work: 6. MIRU Doyon 19 7. Pull BPV 8. Circulate 9.8 ppg brine 9. Install BPV and test in direction of flow to 2,000 psi 10. Nipple down tree; nipple up BOP 11. Test BOP 3,800 psi 12. Pull 31/2" production tubing and lay down 13. RIH and set CIBP @ 2,920 ft. and pressure test 14. Cut 7" casing @ 2,910 ft. 15. Pull and retrieve 7"casing 16. RIH 3-1/2"tubing and spot 17 ppg cement kick off plug.Top of cement 2,520 ft. CD3-111A—Proposed P&A Schematic ' 2 16"62.59 H-40 Welded .•� . j 7 Insulated Conductor Permafrost : 1 i 114'MD/114 TVD I 12-V.."OH TO 2755'MD : .i__ t_ __Y '1 - 1 ,1: I t»'s 9-5/8"4091.-80 BTC-M I 1 I L ' l y4 ; T1 iMT ' EE' A Surface Casing . � S � � � !t 2,721 MD/2;469'-TVD RIIIII I ! ! !.'i`C £ Ing One-Stage Kkk-Off Plug i1 !E .! !Es�F !ri£. TOC2,521 MO/BOC2,920 MD 3E. :.giAn: :HE 3t. S i tli�t 1 f11 t!: -I:t2 '.L - 1.. .I— .. m n'. -i }- t. --- -1- 5 1111111111111f141011 1 i, m... ": Alblan 97 15.8ppg Gass G Abandonment Plug .1'....X7/5, 1:15 i'T Top at 7,100' klblilimiliqlliTi}:Ikt y6tINtiuq .: ''•_''' k GfifiiRr,3V Yajt f '' ::i e4 "5, +e .,R HRZ Z 031/6 264 * ' : 5 9: 4a`,.'p �n 7"2691-80 BTC-M Luiniiiii °,` 5t `5•a > .F - 8 467 MD/6,939'TVD • ;., ,„„, :,.�,... CD3-111A—Rig Workover � ' = : ^w, 'rte7611'.,.t 6-1/8"OH TD 15,073'MD ;;r1iC,'E: <:!i:r;'i:.LF §,:<.:;:Er'i pie e'ei! i 1—Circulate Diesel Freeze Protect Out w/KWFtr l; 2—Remove Tree "'. "to � :iii i i* ii<s€ li!'r:iP 3—Pull Pre Cut 3-Ya"Tubing @ 3,115'MD '''''',-f:.;'.:;,,,.:.,,' '.?X'- '�.. ,u. -' Sidetrack Point 14,177'MD °�°°!°°!�-'� 4—RIH&SetCIBPat"'2,920'MD -,u,. ,y., u � @ 5—Cut&Pull 7"Casingat"',2910'MD 6—Sleeve 101'MD s:t"1 e>:-:::4 8 giili ?': iiaiiaai iii ae €` ` 7—Cement retainer @"'8,130'MD Bottom of Cement Plug @ 9,530' M 'iii i i li i 1. € ,, : : ; :< 8-Nipple @ 8,148'MD s.4:�.�-�s,'904ii E€iii i''` iYi! i'�i i! .!ii;i i is i!is!i iiyi PINNUNNIPREigiiiligigi]ilillilini .„ immillilliiiiiiiiiiiiiiiiiiiiiiilliliiiiiIiiiiimi!yaiwitii! Sidetrack 6-1/8"OH TD 16,645'MD WNS PROD CD3-111 {onocoPhdhps to Well Attributes Max Angie&MD TD 00J I< IOL Wellborn 1IUVd API Field Name Wellbore Statue net(1 MD MICR) Act We(HKB) toraer,,w91.16 :: 501032052600 FIORD NECHELIK PROD 93.85 10,073.20 15,073.0 •-• Comment H25(ppm) Date Annotation End Date KB.Grd(it) `Rig Relearn.Date CD3.111,6A20165-0952 PM SSSV:LOCKED OUT Last WO: 42.61. 3/25/2006 Vemcel schemepc(actua) Annotation Depth MKS) End Dale Annotation Last Mod By End Date Last Tag. Rev Reason:PULL./SET WRDP pproven 8/6/2016 Casing Strings Casing Deaerlptlon OD(in) ID(in) Top(BKB) Set Depth(1tKB) Set Depth(TVD)...WI/Len(I...Grade 'Top Thread _ CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded ' et Insulated HANGER:31.2-- Casing Description OD(In) ID(in) Top(HKB) Set Depth(BKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread SURFACE 95/8 8.835 36.3 2.721.0 2,469.3 40.00 L-80 BTC Casing Description OD(In) ID(In) Top(BKB) Set Depth(1tKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ) PRODUCTION 7 6.276 34.2 8,660.0 6,932.2 26.00 L-80 BTCM i Casing Description OD(In) ID(In) 'Top(BKB) Set Depth(BKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread Lt WINDOW 612 5.000 14,181.0 14,191.0 6,872.9 Casing Deecrlptlon OD(In) ID(In) Top(BKB) Set Depth(f1KB) Set Depth(TVD)...WI/Len g...Grade Top Thread OPEN HOLE 6 1/8 8,660.0 15,073.0 e: {1 Tubing Strings Tubing Description String Ma...ID(In) Top(HKB) Set Depth(ft..Set Depth(TVD)I...WI(lb/ft) Grade Top Connection 'TUBING I 3121 2.9921 31.21 8,159.81 6,788. 11 9.301L-80 18RD EUE Mod I CONDUCTOR 34" Completion Details Insulated� 30.0-114.0 Nominal ID Top(BKB) Top(TVD)(MEI) Top Incl in Item Des Com (In) X0 4.5N3 5';H4 8 31.2 31.2 0.00'HANGER FMC HANGER W/2.23 PUP 3.958 114.8 114.8 0.50-X0 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 2,130.2 1,994.3 38.01 SAFETYVLV 'CAMCO TRMAXX-5E-LOCKED OUT 4/26/2010 2.812 8,017.0 6,721.3 60.35 SLEEVE BAKER CMD SLIDING SLEEVE 2.813 8,100.9 6,761.7 62.43 PACKER BAKER PREMIER PACKER 2.875 8,148.0 6,782.9 63.87 NIPPLE HOWCO'XN'NO GO NIPPLE 2.750 8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 • Other in Hole(Wireline retrievable s,valves,pumps,fish,etc.) SAFETY VLV;2,130.2 I it Top(TVD) Top Incl WRDP',2,130.0 -77 ir Top(1168) 0665) (°) Den Com Run Date ID(In) a 2,130.0 1,994.1 38.00 WRDP 3 12"WRDP W/2.84'PKG(SER HTS-616,98" 8/4/2016 1.250 OAL) stimutabons&Treatments Mln Top Max Film Depth Depth Top(TVD) Btm(TVD) (BKB) (BKB) (8KB) (BKB) Stg• Type Date Com 8,660.0 15,073.0 6,932.2 1 FRAC 4/4/2013 'Nechelik formation FRAC pumping 20-bpm,16/20 Carbo Lite Proppant 345,6204 proppent,3041 bbl total.100%of design. Mandrel Inserts SURFACE,96.3-2,721.0- SI an on Top(TVD) Valve Latch Pod Size TRO Run II N Top(BKB) )BKB) Mahe Model OD(In) Sery Type Type (In) (psi) Run Date Com 1 3,846.7 3,403.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,676.0 4/5/2013 GAS LIFT 3,846 7 .. 2 6,492.3 5,593.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 II 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 IficHeltz Ositerell4 Say End Date Annotation I 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L7 424/2010 NOTE:View Schematic w/Alaska Schema8c9.0 GAS LIFT,8,492.3 v it I GAS LIFT:7.928.8 - i.- I SLEEVE.8.017.0 11 111 PACKER,8 100 0 NIPPLE:8,148.0 WLEG 8,159 PRODUCTION;342-8.000.0 FRAC:8.660.0 t 4 a e L1 WINDOW,14,181.0-14,191.0 a a cl. OPEN HOLE;8,660.0-15,073.0 ° Well Work Justification & Objectives: CD3-111 is being sidetracked and the current open hole lateral needs to be squeezed off with cement and abandoned. Risk/Job Concerns: A) Ensure an approved sundry has been received from AOGCC B) Contact Halliburton a week before the scheduled work date to allow for adequate planning and testing i. Wesley Miller/Ed Jans 907-670-5827 ii.Job design is for 85 bbl. of 15.8#Class "G"cement Steps: Slickline: (Install Dummy Valves) 1) Hold pre-job safety meeting and identify hazards 2) MIRU slickline and auxiliary equipment, pressure test as required 3) RIH and set CSV in the 2.75"XN Nipple @ 8,148 ft. 4) RIH and pull GLV's from station 1 &2 (3,846 ft. & 6,492 ft.) 5) Install 1" DMY valves in stations 1&2 (3,846 ft. &6,492 ft.)and pressure test tubing 6) Pull OV from station 3 @ 7,928 ft. and ensure the well can be circulated 7) Pull CSV and freeze protect well 8)Shut in well; RDMO Slickline Coiled Tubing: (Set Retainer,Squeeze Cement) 1) Hold pre-job safety meeting and identify hazards 2) MIRU coiled tubing and auxiliary equipment, pressure test as required 3) PU 2.75" OD Weatherford one trip cement retainer w/ported bullnose 4) RIH to 2.75"XN nipple @ 8,159 ft. and tag nipple for depth control a)do not pump while RIH 5) Pull up hole 20 ft. and set retainer @ +/-8,128 ft. 6) Close in CT x Tubing annulus • 7) Perform injectivity test, pump 20 bbl. of diesel thru retainer to verify proper set and adequate injection rate 8) RU Halliburton cementing equipment and pressure test as required. 9) Pump 50 bbl. of 15.8 ppg Class "G" cement thru retainer 10)Shut down and un-sting from retainer a)Open IA and prepare to take returns 11) Lay in 35 bbl. above retainer and squeeze thru GLM @ 7,928 ft. a) equates to+/- 1,000 ft. of cement in tubing and IA. b) estimated TOC @ +/-7,150 ft. 12) Pull above TOC and circulate coiled tubing clean 13)Shut in well; RDMO coiled tubing. **allow cement to set for 24 hours before tag and pressure test** Slickline: (Tag TOC, CMIT, DDT) 1) Hold pre-job safety meeting and identify hazards 2) MIRU slickline and auxiliary equipment, pressure test as required 3) RIH and tag TOC @ +/-7,150 ft. 4) Perform CMIT-TxIA to 1,500 psi 5) Perform DDT TxIA 6)Shut in well; RDMO Slickline WNS PROD CD3-111L1 ConocoPhillips ; �Well Attributes Max Angle&MD TD Alaska,IBC, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(11KB) Conops 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 503-111L1,4/122015144.27 PM SSSV LOCKED OUT Last WO 42.61 3/25/2006 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:RESET WRDP Iehallf 3/24/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LI OPEN HOLE 61/8 14,190.0 16,645.0 6,855.3 HANGER;31.2 ; Notes:General&Safety End Date Annotation N43/25/2006 NOTE MULTI-LATERAL WELL CD3-111 8 CD3-111L1 ` i , 4/24/2010 NOTE View Schematic w/Alaska Schematic9.0 • CONDUCTOR 34'Insulated; 38.0.114.0 X0 4.5"x3.51;114.8 SAFETY VLV;2,130.2 �( WRDP;2,130.2 • SURFACE;36.3-2,721 0-a 1111 GAS LIFT,3,846.7 GAS LIFT,6,492.3 GAS LIFT,7,928.8 SLEEVE;8,017.0 1. PACKER;8,100.9. NIPPLE,8,148.0 WLEG;8,159.3 PRODUCTION;34.2-8,660.0 ss# FRAC;8.680.0 It>s L1 WINDOW;14,181.0-14,191.0 OPEN HOLE;8,660.0-15,073.01 /1/i Ittl alta L1 OPEN HOLE;14,190.0- t 1 5 16,645.0 • Loepp, Victoria T (DOA) From: Dai,Weifeng <Weifeng.Dai@conocophillips.com> Sent: Tuesday, February 14, 2017 4:42 PM To: Loepp,Victoria T(DOA) Subject: RE:CRU CD3-111(PTD 206-030); D3-111L1(PTD 206-042,Plug for Redrill; CD3-111A(PTD 217-004)Sidetrac : Modifications Needed'' Attachments: CD3-111A PTD_Final.pdf;Cover letter for PTD.pdf;CD3-111A Re-drill Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Please review the attached files as per request.The cover letter includes the statement that we will frac the well. I add cement program in the PTD and also the schematic attached. Please let me know if any other information is needed. Thanks. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 14,2017 9:37 AM To: Dai,Weifeng<Weifeng.Dai@conocophillips.com>; Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD3-111(PTD 206-030); D3-111L1(PTD 206-042)'lug for Redrill;CD3-111A(PTD 217-004) Sidetrack: Modifications Needed Weifeng, Please provide a cement summary for sidetrack that includes cement volumes,sx,yield,TOC for each stage. Please provide a WBS that shows cement, both stages and depths Also,the cover letter needs to include a statement that the sidetrack will be fracture stimulated. Thanx, Victoria From: Loepp,Victoria T(DOA) Sent:Tuesday, February 14, 2017 9:07 AM To: Dai,Weifeng(Weifeng.Dai@conocophillips.com)<Weifeng.Dai@conocophillips.com>; h.marshall.brown@conocophillips.com Cc: Eller,J Gary(J.Garv.Eller@conocophillips.com)<J.Garv.Eller@conocophillips.com>; Bearden,J Daniel (J.Daniel.Bearden@conocophillips.com)<J.Daniel.Bearden@conocophillips.com> Subject:CRU CD3-111(PTD 206-030);CD3-111L1(PTD 206-042) Plug for Redrill;CD3-111A(PTD 217-004)Sidetrack: Modifications Needed Importance: High Marshall,Weifeng, The plug-for-redrill sundries need to include operations up to milling the window. 1 • • • The plug-for-redrill sundries need a summary paragraph outlining the operations. Need a better wellbore schematic showing the two laterals that are being plugged and plugs with plug depths, retainer depth,TOC etc The MPSP is inconsistent between the plug-for-redrill sundries and the PTD. The BOP test pressure is not sufficient. Needs to be 3800-4000 psig I would suggest you look at a typical Kuparuk plug for redrill sundry and associated sidetrack PTD as a go-by. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoriaioepp@alaska.gov 2 • • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, January 18, 2017 10:25 AM To: 'Brown, H Marshall' Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: RE: CRU1CD3-111L1 (PTD 206-042)Sundry Application Marshall, Cement plugs would be Victoria's area of expertise. However, the AOGCC does need separate paper work associated with the L1 lateral for the current plug proposal so that we can close the paper work on that well. Thanks, Patricia From: Brown, H Marshall [mailto:H.Marshall.Brown@conocophillips.com] Sent: Wednesday,January 18, 2017 9:58 AM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: CRU CD3-111L1 (PTD 206-042) Sundry Application Patricia, That window is 5,521 ft. down the open hole lateral. I spoke with Victoria about not needing to fill the entire lateral with cement (open hole lateral volume is 233 bbl.). Would the Sundry for the CD3-111L1 need extra cement or just separate paper work associated with the L1 lateral for the current plug proposal? Look forward to hearing from you. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO-1309 Office: 907.265.6218 Mobile: 281.732.5844 H.Marshall.Brown@ConocoPhillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,January 18, 2017 9:48 AM To: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> p am Subject: [EXTERNAL]CRU CD3-111L1 (PTD 206-042)Sundry Application Good morning Marshal, AOGCC received the sundry application for CD3-111 (PTD 206-030) for the plug for redrill. However, ConocoPhillips also needs to submit a Sundry Application for the plug for redrill for CRU CD3-111L1 (PTD 206-042). Thank you, 1 • Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Sent: Wednesday,January 18, 2017 9:58 AM To: Bettis ri Subject: 'E: CRU CD3-111L1 (PTD 206-042) Sundry Applicati. Patricia, That window is 5,521 ft. down the open hole lateral. I spoke with Victoria about not needing to fill the entire lateral with cement (open hole lateral volume is 233 bbl.).Would the Sundry for the CD3-111L1 need extra cement or just separate paper work associated with the L1 lateral for the current plug proposal? Look forward to hearing from you. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO-1309 Office: 907.265.6218 Mobile: 281.732.5844 H.Marshall.Brown@ConocoPhillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday,January 18, 2017 9:48 AM To: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111L1 (PTD 206-042)Sundry Application Good morning Marshal, AOGCC received the sundry application for CD3-111 (PTD 206-030) for the plug for redrill. However, ConocoPhillips also needs to submit a Sundry Application for the plug for redrill for CRU CD3-111L1 (PTD 206-042). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and �/ initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • i'Td 7_0c, — 6 9-Z- Loepp, Victoria T (DOA) From: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Sent: Wednesday,January 18, 2017 10:28 AM To: Bettis, Patricia K(DOA) Cc: Loepp,Victoria T(DOA) Subject: RE:CRU CD3-111L1 (PTD 206-042) Sundry Application Follow Up Flag: Follow up Flag Status: Flagged Patricia, Got it,thanks!We will get that paper work in tomorrow. Regards, Marshall Brown SCANNED MAY 3 0 20L From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,January 18,2017 10:25 AM To: Brown, H Marshall<H.Marshall.Brown@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE:CRU CD3-111L1(PTD 206-042)Sundry Application Marshall, Cement plugs would be Victoria's area of expertise. However,the AOGCC does need separate paper work associated with the L1 lateral for the current plug proposal so that we can close the paper work on that well. Thanks, Patricia From: Brown, H Marshall [mailto:H.Marshall.Brown@conocophillips.com] Sent:Wednesday,January 18, 2017 9:58 AM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE:CRU CD3-111L1 (PTD 206-042)Sundry Application Patricia, That window is 5,521 ft.down the open hole lateral. I spoke with Victoria about not needing to fill the entire lateral with cement(open hole lateral volume is 233 bbl.). Would the Sundry for the CD3-111L1 need extra cement or just separate paper work associated with the L1 lateral for the current plug proposal? Look forward to hearing from you. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. 1 ATO-1309 • • Office:907.265.6218 Mobile: 281.732.5844 H.Marshall.Brown@ConocoPhillips.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,January 18,2017 9:48 AM To: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111L1 (PTD 206-042)Sundry Application Good morning Marshal, AOGCC received the sundry application for CD3-111 (PTD 206-030)for the plug for redrill. However,ConocoPhillips also needs to submit a Sundry Application for the plug for redrill for CRU CD3-111L1 (PTD 206-042). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑✓ 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 206-042 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20526-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372105, 364471, 364470 CRU CD3-111L1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 16645 feet Plugs measured None feet true vertical 6855 feet Junk measured None feet Effective Depth measured 16645 feet Packer measured 8101 feet true vertical 6855 feet true vertical 6762 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Intermediate Production 8626' 7" 8660' 6932' Liner $e APR2 1 2RECEIVED Perforation depth Measured Depth: Open hole completion 14190'- 16645' MAR 1 7 2016 True Vertical Depth: 6873'-6855' //�� /'�► AOGCC Tubing(size,grade,measured and true vertical depth) 3.5", L-80, 8160' MD, 6788'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 8101' MD, 6762'TVD SSSV: WRDP-1, 2130' MD, 1994'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 14190'- 16645' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 419 364 152 896 296 Subsequent to operation: 426 414 169 893 299 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerrv.C.Freedman(cDcop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature kW! A,c,t d(.N.. Phone 265-6579 Date 3f/r. (1 (---' ✓T` 4/l-//4 Form 10-404 Revised 5/2015 /ry '� RBDMS kit' MSR 2 1 2016 Submit Original Only • • CD3-111 and CD3-111L1 Scale Inhibition Treatment 2/17/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 02:33 hrs to 23:21 hrs on 2/17/16. LRS= Little Red Services • Initial pressure TBG/IA/OA—538/860/391 • LRS pumped 30 bbls WAW5206/Diesel/M209 preflush at 0.3 bpm,TBG/IA/OA—115/840/66 • LRS pumped 70 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 0.3 bpm,TBG/IA/OA—0/822/19 • LRS pumped 350 bbls Dead Crude overflush at 0.3—0.5 bpm,TBG/IA/OA—0/793/8 Intervals treated: CD3-111—8660'—15073' CD3-111 L1—14910- 16645' `e E WNS PROD • CD3-111L1 • ConocoPhillips Well Attributes Max Angle&MD TD ► Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) AldSka.131,^,. 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 Conrroihitlipr ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-111L1,4/12/2015144:27 PM SSSV:LOCKED OUT Last WO: 42.61 3/25/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason.RESET WRDP lehallf 3/24/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L1 OPEN HOLE 61/8 14,190.0 16,645.0 6,855.3 4ANC:Fk ,z .tlf Notes:General&Safety End Date Annotation 3 5.5.5t 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111 8 CD3-111L1 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 ;l a AMW CONDUCTOR 34'Insulated; 36.0-114.0 0045'x35:114.8 SAFETY VLV',2.130.2 's WRDP,2,130.2 L SURFACE,36.3-2,721.0-A GAS LIFT,3,846.7 I I GAS LIFT',6,492.3 GAS LIFT,7.9288 SLEEVE,8,017.0 PACKER:8,1009 NIPPLE;8.1480 WLEG,8,159.3 PRODUCTION;34.2-8.660 0 FRAC;8.660 0 LI WINDOW;14,181.0-14,191.0' 1 I�.��.� OPEN HOLE,8,660 0-15,073 0 L1 OPEN HOLE,14,190.0- 16,645.0 STATE OF ALASKA AL :A OIL AND GAS CONSERVATION CON. _;SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Scale Inhibitor Treatment J 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 206-042 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service f 50-103-20526-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372105,364471,364470 CRU CD3-111L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Nechelik Oil Pool 11 Present Well Condition Summary: Total Depth measured 16645 feet Plugs(measured) none true vertical 6855 feet Junk(measured) none Effective Depth measured 16645 feet Packer(measured) 8101 true vertical 6855 feet (true vertical) 6762 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Production 8626' 7" 8660' 6932' RECEIVED %Amu UN 0 I Ji 1 7 5c Perforation depth: Measured depth: open hole 14190'-16645' MAY 2015 True Vertical Depth: 6873'-6855' AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 8160 MD, 6788 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 8101 MD/6762 TVD SSSV-CAMCO TRMAXX-5E @ 2130 MD/1994 TVD 12.Stimulation or cement squeeze summary: • Intervals treated(measured): 14190'-16645' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 512 289 171 909 282 Subsequent to operation 535 134 164 971 288 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F." Gas F WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SU SP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O Exempt: none Contact Kerry Freedman (a, 265-6579 Email Kerry.C.Freedman(a�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature / T Phone:265-6579 Date 5-1)y I Ls---- v 77- SVTC '5/2 1 15 RBDMS& MAY 1 5 1015 A 5/28/5' Form 10-404 Revised 5/2015 Submit Original Only CD3-111, CD3-111 L1 Scale Inhibition Treatment 3/27/15 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped 3/27/15,02:30—10:00 hrs LRS= Little Red Services - Initial pressure TBG/IA/OA—908/1010/209 - LRS pumped 120 bbls Diesel/M209/WAW5206 pre-flush at 4-0.1 bpm,TBG/IA/OA— 2070/985/52 - Job discontinued due to low injectivity 4/9/15 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped 4/9/15, 18:45—21:00 hrs LRS= Little Red Services - Initial pressure TBG/IA/OA—321/1208/0 - LRS pumped 40 bbls Diesel/M209/WAW5206 pre-flush via coiled tubing at 1.8-0.3 bpm, TBG/IA/OA—1448/1967/35 - Job discontinued due to low injectivity 4/24/15 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped 4/24/15,09:00—4/25/15 00:00 hrs LRS= Little Red Services - Initial pressure TBG/IA/OA—500/920/310 - LRS pumped 30 bbls Diesel/M209/WAW5206 pre-flush at 0.3 bpm,TBG/IA/OA—250/907/130 - LRS pumped 70 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 0.3 bpm,TBG/IA/OA—0/895/297 - LRS pumped 350 bbls Dead Crude/M209 overflush at 0.3—0.6 bpm,TBG/IA/OA—75/845/5 Interval treated: CD3-111-8660'—15,073' CD3-111 L1—14,190'—16,645' WNS PROD CD3-111L1 ConocoPhillips o Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/DWI Field Name Wellbore Status ncl I°) MD(ftKB) Act Btm(ftKB) [mnnn.lntw 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-111L1,4/12/2015 1:44:27 PM SSSV:LOCKED OUT Last WO: 42.61 3/25/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag: Rev Reason:RESET WRDP lehallf 3/24/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1 OPEN HOLE 6 1/8 14.190.0 16,645.0 6,855.3 HANGER;31.z_i i'ETITNotes:General&Safety 114111 End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L7 a- #a 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 1 I '_I+^6� CONDUCTOR 34'Insulated. 36.0-114.0 XO 4.5,3.5.;114.8 SAFETY VLV;2.130.2 T. WRDP;2.130.2 lC SURFACE;36.3-2.721.0-� GAS LIFT;3,146.7 GAS LIFT 6 492 3 GAS LIFT;7,9281 SLEEVE,8,017.0 PACKER:8.100.9 NIPPLE;8,148.0 MB i WLEG;8,159.3 PRODUCTION;34.2-8.660.0 FRAC;8.660.0 • Lt WINDOW;14.181.0-14,191.0 �a4s r OPEN HOLE;8,660.0.15,073.01 ` tiff tst $ LI OPEN HOLE;14,190.0. aa s 16,645.0 • 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 fife, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ l.~-.~ Well History File Identifier Organizing (done> RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o.wo.,a~ immiiuiiiiiiii DIGITAL DATA Diskettes, No. ^ Other, No/Type: ae,v~~Kaea iuuimiiiuim OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria Date: ~ ~ ~ ~ D ~ /s/ r Project Proofing III IIIIII IIII II III BY: Maria Date: ~ lJ g /s/ Scanning Preparation ~_ x 30 = ~ + __~ =TOTAL PAGES__'T / ( ount does not include cover sheet) BY: Maria Date: ~ ~ !s/ Production Scanning III IIIIIIIIIII IIIII Stage 1 Page Count from Scanned File: ~~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ ~S' ~ ~ /s/ ~n/~ ww ~I~,~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III I-IIII IIIII II III ReScanned II I II II II I I III I (III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III P P 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP RT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon f Repair w ell r Plug Perforations E Perforate E Other fl Alter Casing is Pull Tubing E Stimulate - Frac f;. Waiver r Time Extension r Change Approved Program i Operat. Shutdow n E Stimulate - Other F" Re -enter Suspended Well ,J 2. Operator Name: ✓ 4. Well Class Before Work: v 5. Permit to Drill Number: ✓ ConocoPhillips Alaska, Inc. Development Fro Exploratory f"" 206 -042 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic f Service r 50 103 - 20526 - 60 7. Property Designation (Lease Number): v' 8. Well Name and Number: if ADL 372105, 364471, 364470 CD3 - 111 L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Fiord Nechelik Oil Pool 11. Present Well Condition Summary: Total Depth measured 16645 feet If Plugs (measured) none true vertical 6857 feet Junk (measured) none Effective Depth measured 16645 feet Packer (measured) 8101 true vertical 6857 feet (true vertical) 6761 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Production 8626' 7" 8660' 6932' RECEIVED Perforation depth: Measured depth: open hole 14190'- 16645' SCANNED JUL 10 2013 APR 3 0 2013 True Vertical Depth: 6873' - 6857' AOGGC Tubing (size, grade, MD, and TVD) 3.5, L - 80, 8160 MD, 6788 TVD v. Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 8101 MD and 6761 TVD SSSV - CAMCO TRMAXX -5E SSSV @ 2130 MD and 1994 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14190' - 16645' Treatment descriptions including volumes used and final pressure: ISIP =2403 psi, 345620# of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 940 2187 617 -- 322 Subsequent to operation 2726 1825 323 -- 328 14. Attachments 15. Well Class after work: ✓ Copies of Logs and Surveys run Exploratory I Development f✓ Service i Stratigraphic r 16. Well Status after work: *. Oil W. Gas E WDSPL f Daily Report of Well Operations XXX GSTOR 1 WINJ j WAG E GINJ r SUSP r SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ''. 313 - 078 Contact Robert Blaknev @ 265 - 6417 Email Robert.G.Blaknev( conoc0Phillios.com Printed Name ' ...,-rt Blakney Title Completion Engineer Signature / -_- Phone: 265 -6417 Date ( /'jirFoje RBDMS MAY 12013 -'/ // 3 Form 10 -404 Revised 10/2012 Submit Original Only 1 • • CD3 —111 and 111L Report of Sundry Well Operations This well has 2 separate laterals. The first well bore, CD3 -111, was drilled to a MD of 15,073'. The 2 lateral was an open -hole sidetrack from 14,190' — 16,645'. We assume the fracture initiated near the heel of the well in the CD3 -111 wellbore, but because we cannot be sure of this we are submitting the report for CD3 -111 and CD3-111L together. Please contact me if you have any questions. Thanks, Robert Blakney ConocoPhillips Completions Engineer 907 - 265 - 6417 (office) 505 — 804 - 5246 (cell) ATO 1508, 700 G st. Anchorage, AK B CD3 -111 L1 Well Work Summa DATE SUMMARY • 3/28/2013. GUAGED TBG TO 2.81 TO 2130 RKB. PULLED WRDP f/ SAME. DRIFT TBG TO 2.77 TO XN @ 8148' RKB. SET CAT SV © SAME. IN PROGRESS 3/29/2013 TESTED CAT SV TO 3000 PSI, PULLED 1" OV © 7929' RKB, CIRCULATED 205 BBLS SEAWATER & U -TUBE 75 BBLS CRUDE, SET 1" SPG @ 7929' RKB. MIT TBG TO 3500 PSI (FAILED). FLOWLINE TRACKING WHEN TUBING IS PRESSURED UP, CALL FOR VALVE SERVICE. ATTEMPT TO MIT IA TO 3500 PSI (FAILED). TUBING PRESSURE CAME UP SUDDENLY AFTER 5 MINUTES INTO TEST, FROM 1500 TO 3200 PSI. IN PROGRESS. 3/30/2013 PULLED AND REPLACE SPG IN STA # 3 @ 7929' RKB, SHIFTED CMD CLOSED © 8017' RKB, MIT TBG & IA TO 3500 PSI, BOTH PASSED, PULLED CAT SV FROM XN NIPPLE @ 8148' RKB, SET FRAC ACROSS SSSV @ 2130' RKB & TESTED CONTROL LINE TO 4500 PSI, DRIFT TREE WITH 3.89" G. RING. READY FOR FRAC 3/31/2013 Performed Nechelik formation fracturing treatment pumping 20 -bpm breakdown, then pad, 2 -, 4- and 7- ppa stages; 16/20 CarboLite proppant with 25# linear and x -link gel. Pumped 345,620# proppant, 3041• bbl total volume; 100% of design. 4/4/2013 PULLED FRAC SLV @ 2130' RKB. B &F TBG. PULLED SPARTEK GAUGE AND SET OV (1/4 ") © 7929' RKB. PULLED DV @ 6492' RKB. IN PROGRESS. 4/5/2013 SET GLV (TRO =1730 PORT = 3/16 ") @ 6492' RKB. PULLED DV AND SET GLV (TRO =1676 PORT = 5/32 ") @ 3847' RKB. PULLED CATCHER @ 8148' RKB. SET FRAC SLV © 2130' RKB. COMPLETE. 4/15/2013 PULLED FRAC SLEEVE @ 2130' RKB. ATTEMPT TO CLEAR BAL -0 LINE. NO SUCCESS. SET WRDP -1 ON X -LOCK (S /N: HTS -686/ OAL = 89.5 " / 36.25" NO -GO TO BTM PACKING STACK/ 33" BETWEEN PACKING STACKS). RAN 3" CHECK SET TO 2130' RKB..**PASS CLOSURE TEST**. COMPLETE. WNS ID CD3 -111 L1 Conoc Phillips « Well Attributes Max Angle & MD TD • A last a.ln T Wellbore APINWI Field Name Wellbore Status Inc! ( °) MD (ftKB) Act Btm (ftKB) . (: . conooaPhm,p. 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Well con6a : - c03 111u,4nnzo1a9.39zeAM SSSV: LOCKED OUT Last WO: 42.61 3/25/2006 Schemato - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Pull FRAC SLV, SET WRDP haggea 4/17/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L1 OPEN HOLE 61/8 14,190.0 16,645.0 6,855.3 HANGER, 31 I / Notes: General & Safety `¢ , v End Date Annotation R. a ' 3/25/2006 NOTE: MULTI - LATERAL WELL: CD3 -111 8, CD3 -111L1 ; 4/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 II CONDUCTOR'' 34" Insulated, 6.I 36-114 ((( - X04.5'63.5", l 115 SAFE ,2,130 I - I SAFETY VL 2,130 O SURFACE, • l 38 -2,721 GAS LIFT, 1 G4 3.847 GAS LIFT k . . - 6,IFT FI IN GAS LIFT, I L.... 7,929 L SLEEVE, 8,017 i .I I PACKER, 8,101 I, "3. j.) Mandrel Details NIPPLE. 5,148 l Top Depth Top Port ia 5,,, (TVD) 1001 OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) F) Make Model (!n) Sery Type Type fn) (psi) Run Date Com... 1 3,846.7 3,403.9 33.14 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,676.0 4/5/2013 WLEG, 8,159 ,. 2 6,492.3 5,593.8 34.40 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 3 7,928.8 6,676.2 58.48 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 4/4/2013 I PRODUCTION, 3441,660 i WINDOW. I 4 W1 NDOW, 1, E 4 PEN 91 OPEN HO PN HOLE, 8,860-15,073 LI OPE OPEN HOLE, 14,190 - 18,845 TD (CD3- 111L1). 18,045 STATE OF ALASKA ALIOA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other II✓ Scale Inhibtion Treatment Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension '— Change Approved Program rOperat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Developme J Exploratory r _ 206 -042 3. Address: 6. API Number: Stratigraphic r Service r ,-r P. O. Box 100360, Anchorage, Alaska 99510 CO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 364471, 364470 CD3 - 111 L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Fiord Nechelik Oil Pool 11. Present Well Condition Summary: Total Depth measured 16645 feet Plugs (measured) none true vertical 6857 feet Junk (measured) none Effective Depth measured 16645 feet Packer (measured) 8101 \ true vertical 6857 feet (true vertical) 6761 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Production 8626' 7" 8660' 6932' RECEIVED SCANNED APR 19 2013 Perforation depth: Measured depth: open hole 14190' - 16645' A()GCC True Vertical Depth: 6873' - 6857' Tubing (size, grade, MD, and TVD) 3.5, L -80, 8160 MD, 6790 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 8101 MD and 6761 TVD SSSV - CAMCO TRMAXX -5E SSSV @ 2130 MD and 1994 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14190'- 16645' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p - Service r Stratigraphic r 16. Well Status after work: , Oil j Gas r WDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jack Walker a 265 - 6268 Email Jack .A.Walker(u�conocobhillips.com Printed Name Jack Walker Title WNS Production Engineering Supervisor Signature Phone: 265 -6268 Date i r -( /(/t- tti 4Z6,----0 / 2- kl .a 20 I 3 k ARBDMS MAR 14 2013 vi-r- Form 10 -404 Revised 12/2012 , /�� Submit Original Only � 1 WNS CD3 -111 L1 Conocolifiilhi�i " II— Well Attributes Max Angle & MD TD ,� `* w`m.�13 Wellbore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) ca , a ,„ /kp ef 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "" SSSV: LOCKED OUT Last WO: 42.61 3/25/2006 Well Config - CD3 -111 L1, 511 41201 0 1:00:07 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: RESET WRDP LOCK OUT Imosbor 4/27/2010 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L1 OPEN HOLE 61/8 14,190.0 16,645.0 6,855.3 HANGER. 31 I M .., P Notes: General & Safety 1 End Date Annotation 1 ; .. • P 3/25/2006 NOTE: MULTI - LATERAL WELL: CD3-111 8 CD3 -111L1 4/24/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 CONDUCTOR S 42" Insulated, 36 -114 00 4.513.5 ", it 115 I WRDP,2,130 t I SAFETY VLV, 2,130 1 A M > j I SURFACE, 36 -2,721 1I GAS LIFT, ir:11- , 3,847 all GAS LIFT. 6,492 IF it GAS LIFT, 7,929 SLEEVE, 8,017 I PACKER, 8,101 I Mandrel Details Top Depth Top Port NIPPLE. 8.148 (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (AKB) El Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 3,846.7 3,403.9 33.14 CAMCO KBMG 1 GAS LIFT DMY SBK... 0.000 0.0 4/24/2006 WLEG,8.159 , .. 2 6,492.3 5,593.8 34.40 CAMCO KBMG 1 GAS LIFT DMY SBK... 0.000 0.0 4/24/2006 3 7,928.8 6,676.2 58.48 CAMCO KBMG 1 GAS LIFT OV SBK... 0.250 0.0 4/22/2006 PRODUCTION, 34 -8.660 •. ;* WINDOW. ' 14.181 - 14191 }°(rh -4444ii ;# OPEN HOLE, 8,060- 15,073 L1 OPEN HOLE, 14,190 - 16,645 (CD3- 111L1), " ^ "l 16,645 i • Scale Inhibition Treatment CD3 -111L1 3/7/2013 Initial pressure TBG /IA /OA- 500/1025/128; LRS pumped 12.4 bbl arctic low endpoint diesel containing 102 gal WAW5206, 105 bbl of 70:30 MEG containing 660 gal SCW3001WC, and 400 bbl crude at 2 to 3 bpm. Final pressures 2400/941/VAC. „w)-\ \I i %i- s� THE STATE Alaska Oil Gas �� � � °ALl ALASKA Commission ottt GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 AL Main: 907.279.1 433 ',p�NHED L 11 MI Fax: 907.276.7542 Robert Blakney 6-01+9- Completion Engineer O ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Neechelik Oil Pool, CD3 -111L1 Sundry Number: 313 -078 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31 ,05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i Cathy ' . Foerster Chair DATED this``' day of March, 2013. Encl. STATE OF ALASKA R I° s F D . Al•CA OIL AND GAS CONSERVATION COM•ION APPLICATION FOR SUNDRY APPROVALS ` 20 AAC 25.280 1 . Type of Request: Abandon E Rug for Redrill )"""" Perforate New Pool r,.. Repair w ell r° ctAWAWNeero ram r- Suspend ("` Plug Perforations r Perforate (""- Pull Tubing r Time Extension f Operational Shutdown E Re -enter Susp. Well r Stimulate • Alter casing E Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 1 206 -042 • 3. Address: Stratigraphic (° " Serv ( 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20526 - 60 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes E No Fi CD3 - 111 L1 9. Property Designation Lease Number): 10. Field /Pool(s): ADL 372105, 364471, 364470 Colville River Field / Fiord Nechelik Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16645 6857 - 16645' 6857' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16" 114' 114' SURFACE 2685' 9.625" 2721' 2469' PRODUCTION 8626' 7" 8660' 6932' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • open hole 14190'- 16645' 6873' - 6857' 3.5 L - 8160 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER ° MD =8101 TVD =6761 SSSV - CAMCO TRMAXX -5E • MD =2130 TVD =1994 12. Attachments: Description Summary of Proposal t dI 13. Well Class after proposed work: Detailed Operations Program 1` BOP Sketch Exploratory E Stratigraphic i Development pi •Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil l . Gas r WDSPL I Suspended 16. Verbal Approval: Date: VVINJ (_ - GINJ I WAG r Abandoned l"` Commission Representative: GSTOR E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Robert.G.Blakney(aconocophillips.com Printed Name Robes BI - Title: Completion Engineer ` Signature �'� Phone: 265 -6417 Date �l `5 / Commission Use Only Sundry Number: 1 3 � 8' Conditions of approval: Notify Commission so that a representative may witness 3 Plug Integrity t BOP Test E Mechanical Integrity Test r Location Clearance __ Other. RBDMS MAR 0 5 201 Spacing Exception Required? Yes ❑ No 21 Subsequent Form Required: /6 — 40 !ten s sl APPROVED BY Approved by: / application is va lid 1 1-� tgaa la vad. Date: 3 q- - / 3 Form 10-403 (Revi ed 10/20 l� 0 RIGINAL Su it FO d Attachments in Duplicate 1\\ v, � WNS CD3 -111 L1 COnOCOPh1II1ps $ Well Attributes • Max Angle & MD TD Alaska, Inc Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) A p o 501032052660 FIORD NECHELIK PROD 95.92 16,606.89 16,645.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: LOCKED OUT Last WO: 42.61 3/25/2006 Well Conn() . - CO3-11111, 5/14/2010 1:00:07 PM - Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP LOCK OUT Imosbor 4/27/2010 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd Li OPEN HOLE 61/8 14,190.0 16,645.0 6855.3 HANGER, 31 / Notes: General & Safety } _ End Date Annotation ■ 325/2006 NOTE: MULTI - LATERAL WELL: CD3 -111 & CD3 -111L1 4/24/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 FP I CONDUCTOR 42" Insulated, 36-114 XO 4.5'13.5", 115 WRDP, 2.130 SAFETY VLV, 2,130 }} SURFACE, 36 -2,721 GAS LIFT, 3,847 GAS LIFT, - - 6,492 GAS LIFT 7,929 SLEEVE 8,017 '_ .. I r PACKER, 8,101 ■ Mandrel Details Top Depth Top Port NIPPLE. 8.148 (TVD) 1661 OD Valve Latch Size TRO Run U Ste Top (ftKB) (ftKB) I ") Make Model (in) Sery Type Type On) (psi) Run Date Corn... 1 3,846.7 3,403.9 33.14 CAMCO KBMG 1 GAS LIFT DMY SBK... 0.000 0.04242006 WLEG, 8,159 2 6,492.3 5,593.8 34.40 CAMCO KBMG 1 GAS OFT DMY SBK... 0.000 0.0 4/24/2006 3 7,928.8 6,676.2 58.48 CAMCO KBMG 1 GAS LIFT OV SBK... 0.250 0.0 4/22/2006 PRODUCTION. 34.8,660 WINDOW, 14 HOLE 8, OPEN HOLE. �\ \V 8,660- OPEN L.1 OPEN HOLE, 14,190- 78,845 TD (CD3.111 67 )16,645 • i CD3 —111 and 111L Sundry Application CD3 -111 was completed in 2006 as horizontal producer in the Nechelik formation. The well has 2 separate laterals. The first well bore, CD3 -111, was drilled to a MD of 15,073'. The 2 lateral was an open hole sidetrack from 14,190' — 16,645'. This well is an open hole completion and because of this no frac diversion will be attempted. We assume the fracture will initiate near the heel of the well in the CD3 -111 wellbore, but because we can not be sure we have included a spider map of both wellbores. We expect the increased production to be 200 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: ( Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 2800 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 7,500 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 6000 psi. • 520 bbls YF125ST Pad • 240 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 480 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 400 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 860 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 106 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 340,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. RB • • 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal well until they are clean enough for production.) Production Casing Cement Report: CD3 -111: 7" casing cement pump report on 3/13/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.8 ppg mud. Full returns were seen throughout the job and the floats were checked and they held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. RB • • Stimulation Surface Rig -Up s w P y Bleed Tale Tank Mill x`11 Moe Tale Tank ii 1., 0 $ • Minimum pressure rating on all surface treating lines 10,000 psi >► M Dal • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi g G M IMI • Frac pump trip pressure setting are staggered 3 and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 C i psi. i L tl dwnd V Pop-OtT Tank d Ti; Pump Truck Pop -Off Tank cM ri ti ♦1 A `v 0t •€ .niii L Frac Pump . { tH -081c--it j- Frac Pump Frac Pump N-- �^�, - I Frac Pump 2 Frac Pump N 3-- --lJ-- - Frac Pump RB • i Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MARvDREL INSERT f:151r' FRAC IRON CONNECTION D... r / r r ., . am -- _ MASTER OPERATED � MASTER VALVE . ,,., 1 i,t, MANUAL OPERATED F MASTER VALVE Jlr.r 1 . fax, 4 ,14, «ir_ Stinger 1) 1 /'� Stinger dew 7 ,...... 'II 111' f MANDREL I ... _. 6 ....„,, , .,, Lir\---i , ,-/? , = I VENT lit \„ Q 1 +1--- VALVE °` k �y OPEN � 'i fa I ?tit ,11I : ‘ea- S *,. ■< ®1 01 �\ �ti FLOW TEE AND C f' ■I • VENT VALVE WELLHEAD � .i ,3 .:, , lea - , VALVES �• , r � f /fi. OPEN r • „ I I� a �, ^ IT k4 ■C Nlirk '2 � u 4, I',`" 0 _ a WELLHEAD .� . VALVES . 11 aoseD j� 4 5 i L: \ .. l ■ QUAD PACKOFF AI �A� ASSEMBLY IN if. •r. , PLACE IN TUBING k IN \ Vii® TUBING 1... • • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 V2 tubing and 1.75" down 3 1 /2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB • CD3-1 11 Nechelik Frac Model • Frac Design Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. • Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (gal) (Ib/mgal) (PPA) Pad 40.0 YF125ST 21840 25.0 0.00 2.0 PPA 40.0 YF125ST 92b9 25.0 CarboLite 16/20 2.00 4.0 PPA 40,0 YF125ST 17157 25.0 CarboLite 16/20 4.00 4.0 PPA 40.0 YF125ST 14297 25.0 CarboLite 16/20 4.00 7.0 PPA 40.0 YF125ST 27650 25.0 CarboLite 16/20 7.00 Flush 40.0 WF125 un 25.0 0.00 Fluid Totals III 90212 gal . of . YF125ST 6722 gal of . WF125 Proppant Totals 337900 lb of CarboLite 16/20 Model Results Initial Fracture Top ND ,_. 6960.0 ft Initial Fracture Bottom ND 7010.0 ft • Propped Fracture Half- Length. ......... ..... 375.4 ft EOJ Hyd Height at Well 140.8 ft Average Propped Width in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. 1 CD3 -119 .. CD3 -109 • • CD3-106 • CD3 -108 • • CD3 -106L1 • It. CD3 -110 • ED3- 119PB1 • : • 4 • • CD3 -30'h • CD3 -10L1 x • • CD3 -301A CD3- 301PB1 ii CD3 -11 CD3 - ° =107 FIORD F a• a CD3-113 Legend • • • Well Suspended • h 3- 301APB1 • P +A + Service • Producer CD3 - 114 • Observation • Injection: SW • Injection: SAPW • Injection: PW • • Injection: MWAG • ACTIVE, INJ, MG • ACTIVE, INJ, IWAG ,\ • ACTIVE, INJ, GAS CD3 - 115 CO3 l • ACTIVE, INJ, DG • , • Disposal Null l ' raBu ▪ F c 3 •i :; Well Name • • i • CD3 -111 IN CD3 -111L1 " f - ConocoPhillips Operated Units • 1 • t i+•• • ''1 W.,, t r 21 Nanuq Nanuq Participating Area • f /� i. w, „ F, NPR -A boundary 3 • �. 1 ± I . • . t � ti `. � CortocaPhllips • r : • 1 ;r CD3 -111 and CD3-111L1 ' = • • ,'�� Fracture Locations i '4 • •e • ' , � '•'•" N CONFIDENTIAL `• ti r, '« 1'� .`� „•✓ , \ 0 0 .25 0 .5 • ' Miles I ......e =�`;,, _ _ -• . .......... .. _ . .• FracProwam2013.mxd CSR 1 -10 -2013 4 ~{~ t~~ s ~ ~i1~e 't ~~` ~- ~: - ~' A "".~\~~ MICROFILMED 6!30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc i ~S DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060420 Well Name/No. COLVILLE RIV FIORD CD3-111 L1 Operator CONOCOPHILLIPS ALASKA INC MD 16645 TVD 6857 Completion Date 3/25/2006 Completion Status 1-OIL REQUIRED INFORMATION Mud log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Logl Electr Data Digital Dataset Tvner Med/Frmt Number Name ED D Asc Directional Survey C Lis 13937t~l~iduction/Resistivity t 13937 LIS Verification C Lis 15012 ~ uctionlResistivity Well Cores/Samples Information: Name ADDITIONAL INFORN~,TION Well Cored? Y J]~ Chips Received? ~Pl- Analysis ~YJ~J- Received? Comments: Samples No API No. 50-103-20526-60-00 Current Status 1-OIL UIC N Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 14176 16645 Open 6/27/2006 0 0 Open 6/8/2006 GR, NPHI, NCNT, RHOB, ROP 0 0 Open 6/8/2006 LIS 2697 16645 Open 4/17/2007 LIS Veri, GR, NPHI, NCNT, FCNT, FET, RHOB,DRHO,ROP w/Graphics CGM, EMF, PDF Sample Interval Set Start Stop Sent Received Number Comments Compliance Reviewed By: _ ____ __.___ ____ Daily History Received? ~1'N Formation Tops ~./ N Date: WELL LOG TRANSMITTAL To: State of Alaska April 17, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-111 &CD3-111 Ll, AK-IVIW-4254172 CD3-111 &CD3-111 L1: LIS & Digital Log Images: 1 CD Rom 50-103-20526-00, 60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~~ ~ ~ ~~~ -,, Date: Signed: ill a~ ~ s e~issic~ __ a f~r~-- 20~ -~3v ~ !S 6t~ ao~ - aria lSO~a '3 C7 • 17-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-111 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 14,176.56' MD Window /Kickoff Survey: 16,606.89' MD (if applicable) Projected Survey: 16,645.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Cari Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed - Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) vZ, ~ C~ - b ~~. • C7 WELL LOG TRANSMITTAL To: State of Alaska June 02, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-111 L1, AK-MW-4254172 The technical data listed below is being submitted herewith. Please acknowledge receipt by retluning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20526-60. ~' ~/ ,1UN 0 62006 t'~1- ~o~ - wit ~ X39 3~ ~fi ~ Gas Cons. Gommissiot~ Anclx~3~ a..P~- • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT •A wi ~ f~,..-~ AN [3 L0 1a. Well Status: Oil a Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development O Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 25, 2006 12. Permit to Drill Number: 206-042 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 6, 2006 13. API Number: 50-103-20526-60 4a. Location of Well (Governmental Section): Surface: 1334' FSL, 874' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: March 22, 2006 14. Well Name and Number: CD3-111L1 At Top Productive Horizon: 188' FSL, 173' FEL, Sec. 31, T13N, R5E, UM 8. KB Elevation (ft): 36.6' RKB 15. Field/Pool(s): Colville River Field Total Depth: 1515' FSL, 48T FWL, Sec. 30, T13N, R5E, UM 9. Plug Back Depth (MD + ND): 16645' MD / 6857 ND Fiord NeChelik Oil Pool p ~v+d ~(K.1~. ~'lI°d/ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388169 y- 6003829. Zone- 4 10. Total Depth (MD + ND): 16645' MD / 6857' ND 16. Property Designation: ADL 372105, 364471, 364470 TPI: x- 386283 y- 6007991 Zone- 4 Total Depth: x- 381770 . - 6014669. Zone- 4 11. Depth where SSSV set: SSSV @ 2130' 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1270' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 84# J-55 36.6' 114' 36.6' 114' 24" 10 cu yds Portland Type III 9-5l8" 40# L-80 36.6' 2721' 36.6' 2469' 12.25" 41 o sx Class G, 23o sx Class G 7" 26# L-80 36.6' 8660' 36.6' 6932' 8.75" 19o sx Class G 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 8160' 8101' open hole completion from 14190' - 16645' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production flowback on 4/26/06 Method of Operation (Flowing, gas lift, etc.) flowback Date of Test 4/26/2006 Hours Tested Production for Test Period --> OIL-BBL 4234 GAS-MCF 1294 WATER-BBL CHOKE SIZE not available GAS-OIL RATIO not available Flow Tubing press. 607 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Y q Submit core chips; if none, state "none". c~4T^ NONE ~t~DMS I~FI~ JUN `~ ~ 2006 ~ VfJ?IFEFO ~' Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ rr '~'~ ~~ ~~ ~~ .~~~~ r ~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-111 L1 Nechelik 8571' 6919' N/A 30. LIST OF ATTACHMENTS Summary of Daiiy Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chi Alvord Title: Aloine Area Drillino Team Leader Signature ~ /+G~-. Phone Date ~ ~ ~ ~' INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • CD3-111 Well Events Summary • Date Summary 03/04/06 Repair cable tray. Move rig to CD3-111. 03/05/06 Move rig to CD3-111. 03/06/06 Spud and drilled from 114' to 1,358'. 03/07/06 Drilled to 2731' TD -Circ - WT to HWDP -POOH on TT - LD bit &MWD 03/08/06 Finish LD BHA - RU & run 9 5/8" csg to 2721' - Cmt csg - RD cmt &csg equip - RU & test BOPE 03/09/06 MU BHA #2 - RIH to 136' -Work on TD -Cont. RIH w/ BHA to 287' -test tools - RIH to 2371' - S&C drill line -Test csg to 2500 psi -Clean out shoe track & drill to 2753' -Perform LOT to 17.4 ppg -Drill to 3612' 03/10/06 Drill f/ 3612' to 6665' 03/11/06 Drill f/ 6665' to 8670 03/12/06 Circ btms up -Wiper trip to 7811' -RIH -Circ clean -POOH (spot tube pill) to top of HRZ -POOH on TT f/ 7811' - LD BHA - RU & run 7" csg 03/13/06 Finsih running 7" csg -Circ - Cmt 7" csg -Set & test pack.- off - MU BHA # 3 03/14/06 RIH w/ BHA to 8,016'. Slipped and cut Drilling line. Tested casing to 3,500 psi. RIH to TOC @ 8,464'. Drilled shoe track and 20' to 8,690'. CBU. FIT to 12.6 PPG. Changed Mud to FloPro while drilling. 03/15/06 Drilled to 10,657'. Circulated trouble shooting MWD. POOH with pump. 03/16/06 POOH changed BHA. RIH to 6,102'. 03/17/06 RIH. Drilled from 10,657 to 12,878'. Serviced rig. - - - - 03/18/06 Repaired Top Drive. Drilled from 12,878' to 14,440'. 03/19/06 Drilled from 14,440' to 15,073'. CBU. POOH to 119'. 03/20/06 POOH. Laid down BHA. Tested BOP. Made up and RIH with new BHA to 8, 082'. 03/21/06 Side tracked form 14,190' to 14,225'. Drilled Leg 1 from 14,225' to 14,952'. 03/22/06 Drilled from 14,952' to 16,645'. Observed well losing 80 BPH. 03/23/06 CBU. POOH with pump from 16,645' to 8,654'. Changed over to brine. Laid down DP from derrick. 03/24/06 POOH laid down DP and BHA. Rigged up and ran Completion string. Laid down 4" HWDP> 03/25/06 ND BOPE. NU and test tree. Displace well with treated brine and diesel for freeze protection. Set pkr. Test tbg to 4800 psi. Test annulus to 3500 psi. Set BPV. Release rig. 04/14/06 BPV PULLED BY FMC REP. UNABLE TO GET PAST SSSV @ 2130' RKB. THERE MIGHT BE ICE IN CONTROL LINE OR SSSV IS NOT EQUILIZING. IN PROGRESS. 04/15/06 UNABLE TO GET PAST 2111' SLM SSSV @ 2130' RKB. RECOVERED SAMPLE OF SLUSHY SCHMOO & SOME WATER. JOB SUSPENDED UNTIL PUMP IS AVAILABLE. 04/15/06 PRESSURE UP TBG TO 3500 PSI W/ CONTROL LINE @ 6500 PSI BUT WAS STILL UNABLE TO GET PAST FLAPPER @ 2111' SLM. ALSO SURGED TBG PRESSURE FROM 1000 PSI TO 3500 PSI SEVERAL TIMES BUT STILL NO GOOD. RECOVERED SMALL AMOUNT OF FILL IN SAMPLE BAILER BUT HAD MARKS 04/16/06 STILL UNABLE TO GET PAST SSSV FLAPPER @ 2130' RKB. CONTROL LINE STILLS APPEARS TO FROZEN. PRESSURE TBG UP TO 4800 PSI WHILE WORKING SLICKLINE7OOLS-UNABLE TO PASS FLAPPER. THERE COULD STILL BE EXCESSIVE PRESSURE BELOW FLAPPER OR AN ICE PLUG JUST BELOW THE • 04/20/06 TAG NO GO AND SOFT SET NO GO 2.85" CENT WITH SPACER /PRONG 113" CENT TO BULL NOSE, 150" OAL W/1 3/4" RS FN @ 2130 RKB 04/21/06 PUMP FLAPPER OPEN W/8000# OF PRESSURE, PULL NO GO & PRONG @ 2130' RKB, SET FRAC SLEEVE @ SAME IN PROCESS 04/22/06 PULL 1" DMY @ 7929' RKB, PULL FRAC SLEEVE @ 2130' RKB, RE-SET FRAC SLEEVE @ SAME, THAW C/L LINE W/40 BBLS HOT DIESEL, PULL BALL & ROD @ 8148' RKB, ROD AND BALL MISSING OFF ROLLER STEM. FISH ON TOP OF RCH BODY. SET 1" OV @ 7929' RKB, IN PROGRESS 04/23/06 FISH APPROX, 4' of BROKEN BALL & ROD FROM PLUG BODY @ 8148' RKB, PULL DMY's FROM 3847' & 6492' RKB, IN PROGRESS 04/24/06 SET 1" DMY's @ 3847' & 6492' RKB, PULL EMPTY RHC PLUG BODY FORM XN NiPPLE @ 8148' RKB, SBHPS WITH SURVEY STOP @ 8200' RKB & GRADIENT STOP @ 8000' RKB 04/26/06 SURFACE TESTING RESULTS: PWS FLOWBACK BEGAN WITH NITROGEN LIFT @ 1700 HRS ON 4/24 AND WAS COMPLETED 44 HOURS LATER ON 4/26. DURING FLOWBACK WELL PRODUCED A TOTAL OF 2,735 BBBLS OF OIL, 1,163 TOTAL BBLS OF WATER AND 1,041 MSCF .GAS ;AVERAGE RATE OF 2000 BO 04/28/06 SET 3.5" FRAC SLEEVE @ 2130' RKB 04/30/06 SECURE WELL, FMC SET BPV -well previously displaced with 25 bbl diesel post flowback • Halliburton Compan~ Global Report Company:. ConocoPhilRpsAlaska Inc. Datr. 4/1.0/2006 "fimc: 13:13:56 Pade: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD3-111, Tr ue North Site: Alpine CD3 Vertical (TVD) Reference: CD3-111 L1: 49.4 ~~'ell: CD3-111 Section (VS) Reference: Well (O.OON,O.OOE ,328.59Azi) I Wellpath: CD3-111L1 Survey CalculationDlethod: Minimum Curvature Db: Oracle Survey: Start Date: i Company: Engineer: ~ Tool: Tied-to: Field: Colville River Unit North Slope Alaska United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ~ Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD3 ~ I Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W i Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.00 deg Well: CD3-111 Slot Name: Alpine CD3 Well Position: +N/-S -62.61 ft Northing: 6003828.95 ft Latitude: 70 25 9.865 N +E/-W -318.07 ft Easting : 388169.16 ft ~ Longitude: 150 54 39.718 W Position Uncertainty: 0.00 ft Wellpath: CD3-111L1 Drilled From: CD3-111 501032052660 Tie-on Depth: 14176.56 ft Current Datum: CD3-111 L1: Height 49.40 ft Above System Da tum: Mean Sea Level Magnetic Data: 3/3/2006 Declination: 23.50 deg Field Strength: 57513 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 36.10 0.00 0.00 328.59 Survey Program for De£mitive Wellpath ~ Date: 4/10/2006 Validated: No Version: 1 i Actual From To Survey Toolcode Tool Name ft ft 81.00 442.00 CD3-111 gyro (81.00-442. 00) (0 CB-GYRO-SS Camera based gyro single shot ~ 568.95 14176.56 CD3-111 (568.95-15036.25) (0) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC 14190.00 16606.89 CD3-111 L1 (14190.00-16606.89) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ Survey ~ MD Incl Azim TVD Sys TVD N7S E/W R1apN blapE Tool ~ ft deg deg ft ft ft ft ft_ ft 36.10 0.00 0.00 36.10 -13.30 0.00 0.00 6003828.95 388169.16 TIE LINE 81.00 0.50 208.00 81.00 31.60 -0.17 -0.09 6003828.78 388169.07 CB-GYRO-SS ~ 169:00 0.50 224.00 169:00 119:60 -0.79 -0.54 6003828.17 388168.61 CB-GYRO-SS ~ 260.00 0.85 240.00 259.99 210.59 -1.41 -1.40 6003827.56 388167.74 CB-GYRO-SS 350.00 0.85 266.00 349.98 300.58 -1.79 -2.64 6003827.20 388166.49 CB-GYRO-SS 442.00 1.80 308.00 441.96 392.56 -0.95 -4.46 6003828.07 388164.68 CB-GYRO-SS 568.95 4.95 328.80 568.67 519.27 4.96 -8.87 6003834.05 388160.36 MWD+IFR-AK-CAZ-SC 658.15 7.59 346.95 657.34 607.94 14.00 -12.20 6003843.13 388157.18 MWD+IFR-AK-CAZ-SC ', 747.80 10.59 348.17 745.86 696.46 27.83 -15.22 6003857.00 388154.36 MWD+IFR-AK-CAZ-SC 838.87 13.31 344.72 834.94 785.54 46.14 -19.70 6003875.37 388150.15 MWD+IFR-AK-CAZ-SC ~ 933.72 15.77 340.80 926.75 877.35 68.85 -26.82 6003898.18 388143.38 MWD+IFR-AK-CAZ-SC 1029.11 18.32 339.66 1017.94 968.54 95.15 -36.30 6003924.62 388134.30 MWD+IFR-AK-CAZ-SC 1124.24 20.03 337.84 1107.79 1058.39 124.26 -47.64 6003953.90 388123.39 MWD+IFR-AK-CAZ-SC 1219.20 20.54 334.70 1196.87 1147.47 154.38 -60.89 6003984.21 388110.59 MWD+IFR-AK-CAZ-SC 1314.35 21.38 334.60 1285.72 1236.32 185.14 -75.47 6004015.18 388096.48 MWD+IFR-AK-CAZ-SC 1409.28 23.01 334.86 1373.61 1324.21 217.57 -90.77 6004047.84 388081.67 MWD+IFR-AK-CAZ-SC 1504.78 24.50 337.62 1461.02 1411.62 252.78 -106.24 6004083.27 388066.73 MWD+IFR-AK-CAZ-SC Halliburton Compan Global Report - _ _ Company: ConocoPhillips Alaska Inc. Field: Colville River Unit ', Site: Alpine CD3 Well: CD3-111 ~Vcllpath: CD3-111 L1 - -- - - --_~ T -._---- llate: 4/10/2006 Time: 13:13:56 Pa~,c: 2 Co-ordinatc(NE) Reference: Well: CD3-111, True North Vertical (CVD) Reference: CD3-111 L1: 49.4 Section (VS) Reference. Well (O.OON,O.ODE,328.59Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ~ Survey liD Incl Azim TVD Sys TVD N/S E/W Plap\ MapE Tool ft deg .deg ft ft _ _ ft _ - ft _ - - _ ~ ft .__ _-- -- ft _ _-_ _. _ _- __ _ -_ _ _- - - 1599 r _ _ _ .99 _--- _--- 25.99 ---- 340.64 1547 .14 _ . , 1497 .74 290.72 -120 .67 6004121 .42 388052.86 MWD+IFR-AK-CAZ-SC 1694 .42 28.42 340.75 1631 .12 1581 .72 331.46 -134 .94 6004162 .37 388039.21 MWD+IFR-AK-CAZ-SC 1789 .95 30.43 339.62 1714 .32 1664 .92 375.61 -150 .87 6004206 .74 388023.95 MWD+IFR-AK-CAZ-SC ~ 1884 .71 32.52 338.90 1795 .13 1745 .73 421.87 -168 .39 6004253 .26 388007.12 MWD+IFR-AK-CAZ-SC I 1978 .83 35.51 337.25 1873 .14 1823 .74 470.69 -188 .08 6004302 .37 387988.17 MWD+IFR-AK-CAZ-SC j 2075 .23 37.24 336.37 1950 .76 1901 .36 523.24 -210 .60 6004355 .24 387966.44 MWD+IFR-AK-CAZ-SC 2169 .98 38.56 337.20 2025 .52 1976 .12 576.73 -233 .53 6004409 .06 387944.31 MWD+IFR-AK-CAZ-SC 2265 .75 39.59 337.61 2099 .87 2050. 47 632.46 -256 .72 6004465 .13 387921.96 MWD+IFR-AK-CAZ-SC 2360 .96 38.21 336.46 2173. 96 2124. 56 687.51 -280 .04 6004520 .52 387899.47 MWD+IFR-AK-CAZ-SC 2456 .29 35.92 337.00 2250 .03 2200. 63 740.29 -302 .75 6004573 .63 387877.56 MWD+IFR-AK-CAZ-SC 2550 .00 32.87 337.28 2327. 35 2277. 95 789.06 -323 .31 6004622 .70 387857.73 MWD+IFR-AK-CAZ-SC 2646 .36 34.16 336.08 2407 .68 2358. 28 837.91 -344 .38 6004671 .86 387837.40 MWD+IFR-AK-CAZ-SC 2684 .10 34.24 336.12 2438 .90 2389. 50 857.31 -352 .98 6004691 .37 387829.09 MWD+IFR-AK-CAZ-SC , 2726 .67 34.78 336.27 2473 .98 2424. 58 879.37 -362 .71 6004713 .58 387819.69 MWD+IFR-AK-CAZ-SC 2821 .73 34.49 337.30 2552 .19 2502. 79 929.02 -384 .01 6004763 .54 387799.14 MWD+IFR-AK-CAZ-SC 2917 .22 34.31 334.83 2630. 99 2581. 59 978.32 -405 .89 6004813 .16 387778.01 MWD+IFR-AK-CAZ-SC 3012 .84 34.44 336.05 2709. 91 2660. 51 1027.43 -428 .33 6004862 .59 387756.31 MWD+IFR-AK-CAZ-SC ~ 3108 .26 33.59 334.18 2789. 00 2739. 60 1075.85 -450. 78 6004911 .34 387734.59 MWD+IFR-AK-CAZ-SC 3203 .77 34.14 334.38 2868. 31 2818. 91 1123.80 -473. 87 6004959 .62 387712.21 MWD+IFR-AK-CAZ-SC 3299 .28 34.97 333.35 2946. 97 2897. 57 1172.43 -497. 74 6005008 .60 387689.08 MWD+IFR-AK-CAZ-SC 3394 .52 34.76 332.94 3025. 11 2975. 71 1221.00 -522. 33 6005057 .53 387665.22 MWD+IFR-AK-CAZ-SC 3490 .05 33.87 334.78 3104. 02 3054. 62 1269.33 -546. 07 6005106 .21 387642.22 MWD+IFR-AK-CAZ-SC 3585 .67 33.00 333.11 3183. 81 3134. 41 1316.67 -569. 20 6005153 .88 387619.80 MWD+IFR-AK-CAZ-SC 3681 .13 32.38 335.78 3264. 16 3214. 76 1363.16 -591. 44 6005200 .70 387598.25 MWD+IFR-AK-CAZ-SC ~ 3776 .66 32.22 336.67 3344. 91 3295. 51 1409.88 -612. 02 6005247 .72 387578.38 MWD+IFR-AK-CAZ-SC ~ 3872 .05 33.33 338.81 3425. 11 3375. 71 1457.67 -631. 57 6005295 .79 387559.55 MWD+IFR-AK-CAZ-SC 3967. 19 34.03 338.13 3504. 28 3454. 88 1506.74 -650. 93 6005345 .14 387540.93 MWD+IFR-AK-CAZ-SC 4062. 69 34.96 336.85 3582. 99 3533. 59 1556.70 -671. 64 6005395. 40 387520.97 MWD+IFR-AK-CAZ-SC li 4158. 14 35.56 336.47 3660. 93 3611. 53 1607.29 -693. 47 6005446. 31 387499.90 MWD+IFR-AK-CAZ-SC ~ 4253. 58 35.42 336.71 3738. 64 3689. 24 1658.14 -715. 49 6005497. 48 387478.65 MWD+IFR-AK-CAZ-SC 4348. 45 34.60 334.36 3816. 35 3766. 95 1707.68 -738. 02 6005547. 35 387456.87 MWD+IFR-AK-CAZ-SC 4444. 43 34.59 332.55 3895. 36 3845. 96 1756.42 -762. 37 6005596. 45 387433.25 MWD+IFR-AK-CAZ-SC 4539. 88 34.16 333.03 3974. 14 3924. 74 1804.35 -787. 01 6005644. 73 387409.33 MWD+IFR-AK-CAZ-SC ~ 4635. 21 33.41 332.06 4053. 37 4003. 97 1851.39 -811. 45 6005692. 13 387385.61 MWD+IFR-AK-CAZ-SC 4730. 86 33.32 334.10 4133. 26 4083. 86 1898.29 -835. 26 6005739. 38 387362.50 MWD+IFR-AK-CAZ-SC 4826. 48 33.02 335.41 4213. 30 4163. 90 1945.61 -857. 57 6005787. 02 387340.90 MWD+IFR-AK-CAZ-SC 4921. 57 33.40 335.55 4292. 86 4243. 46 1992.99 -879. 19 6005834. 72 387320.00 MWD+IFR-AK-CAZ-SC it 5016. 94 33.65 336.89 4372. 36 4322. 96 2041.19 -900. 42 6005883. 22 387299.49 MWD+IFR-AK-CAZ-SC 5112. 33 33.35 335.88 4451. 91 4402. 51 2089.43 -921. 51 6005931. 77 387279.13 MWD+IFR-AK-CAZ-SC I 5207. 59 34.10 337.09 4531. 13 4481. 73 2137.93 -942. 61 6005980. 57 387258.76 MWD+IFR-AK-CAZ-SC 5303. 06 33.87 336.66 4610. 30 4560. 90 2187.00 -963. 57 6006029. 95 387238.54 MWD+IFR-AK-CAZ-SC 5397. 98 34.16 337.33 4688. 98 4639. 58 2235.88 -984. 32 6006079. 13 387218.53 MWD+IFR-AK-CAZ-SC ~ 5491. 55 34.36 336.94 4766. 31 4716. 91 2284.41 -1004. 78 6006127. 96 387198.79 MWD+IFR-AK-CAZ-SC 5587. 78 34.16 337.16 4845. 84 4796. 44 2334.30 -1025. 91 6006178. 15 387178.42 MWD+IFR-AK-CAZ-SC ~i 5683. 93 33.74 335.99 4925. 60 4876. 20 2383.57 -1047. 25 6006227. 73 387157.82 MWD+IFR-AK-CAZ-SC 5779. 93 33.83 335.36 5005. 39 4955. 99 2432.21 -1069. 24 6006276. 70 387136.56 MWD+IFR-AK-CAZ-SC 5875. 59 34.50 336.55 5084. 54 5035. 14 2481.27 -1091. 12 6006326. 07 387115.42 MWD+IFR-AK-CAZ-SC I, 5968. 84 34.35 336.29 5161. 46 5112. 06 2529.59 -1112. 21 6006374. 70 387095.06 MWD+IFR-AK-CAZ-SC 6066. 05 33.42 335.81 5242. 16 5192. 76 2579.12 -1134. 21 6006424. 55 387073.81 MWD+IFR-AK-CAZ-SC 6161. 28 33.40 334.19 5321. 66 5272. 26 2626.64 -1156. 37 6006472. 39 387052.37 MWD+IFR-AK-CAZ-SC 6256. 72 34.35 334.45 5400. 90 ~ 5351. 50 2674.58 -1179. 42 6006520. 67 387030.04 MWD+IFR-AK-CAZ-SC ~ 6351. 54 35.32 333.37 5478. 72 5429. 32 2723.22 -1203. 24 6006569. 65 387006.95 MWD+IFR-AK-CAZ-SC 6447. 11 34.95 333.70 5556. 88 5507. 48 2772.45 -1227. 76 6006619. 25 386983.18 MWD+IFR-AK-CAZ-SC Halliburton Compan Global Report Company: ConocoPhillips Alaska lnc. Field: Colville River Unit Site: Alpine CD3 Well: CD3-111 ~ ~V'ellpath: CD3-111 L1 Surve} ------ NID Incl :+,zim ft deg deg ~ 6542.67 34.62 333.58 6638.37 35.03 334.15 ' 6733.77 35.03 335.59 I 6829.22 34.11 335.26 6924.72 34.56 334.84 i 7020.10 34.40 334.16 ~ 7115.62 34.80 335.78 7211.32 34.24 334.53 7304.54 36.73 332.98 7402.02 41.06 332.81 7497.95 45.72 333.03 ~ 7593.32 47.19 332.19 7687.73 50.43 332.63 7784.11 53.01 332.22 7879.52 56.50 331.03 7975.00 59.46 331.01 8069.05 61.45 330.70 I 8165.97 64.42 330.39 8259.93 67.38 329.63 8356.45 70.43 329.76 8452.09 73 .67 328. 77 8547.27 78 .57 328. 96 8642.12 84 .13 329. 33 8737.04 86 .23 331. 50 8832.94 86 .93 330. 13 8928.47 86 .86 329. 07 9023.96 87 .11 326. 42 9119.36 90 .14 323. 70 9214.38 91 .00 321. 89 9308.47 91 .31 322. 35 9405.05 90 .94 320. 74 9498.91 92. 79 322. 55 9595.79 91. 80 322. 19 9690.52 91. 80 323. 10 9785.32 90. 57 323. 93 9881.99 92. 11 324. 01 9977.31 92. 60 324. 55 10073.19 93. 85 325. 46 10168.29 91. 49 322. 28 10261.66 92. 72 322. 82 10359.12 91. 67 322. 76 10454.59 90. 44 322. 84 10549.88 92. 36 323. 14 10645.85 91. 61 324. 65 10741.25 89. 64 324. 74 10836.62 89. 70 325. 28 10930.76 91. 19 325. 96 11027.25 91. 00 326. 78 11117.19 89. 46 326. 94 11211.68 88. 65 325. 26 11313.07 89. 21 325. 66 11409.06 88. 10 325. 53 'TV D ft--- 5635.36 5713.92 5792.04 5870.64 5949.50 6028.12 6106.75 6185.60 6261.50 6337.35 6407.05 6472.75 6534.91 6594.62 6649.67 6700.29 6746.66 6790.76 6829.12 6863.85 6893.33 6916.15 6930.41 6938.39 6944.11 6949.28 6954.31 6956.60 6955.65 6953.75 6951.86 6948.80 6944.92 6941.95 6939.99 6937.73 6933.81 6928.42 6923.99 6920.56 6916.82 6915.07 6912.74 6909.41 6908.37 6908.92 6908.19 6906.35 6905.99 6907.54 6909.44 6911.69 6859.52 6858.79 6856.95 6856.59 6858.14 6860.04 6862.29 N/S -ft 2821.30 2870.37 2919.94 2969.19 3018.03 3066.77 3115.91 3165.12 3213.64 3268.11 3326.77 3388.15 3451.11 3518.16 3586.70 3657.51 3728.97 3804.11 3878.38 3956.12 4034.31 4113.38 4193.85 4276.09 4359.66 4441.94 4522.57 4600.74 4676.41 4750.66 4826.27 4899.83 4976.50 5051.76 5127.96 5206.11 5283.44 5361.85 5438.56 5512.64 5590.20 5666.23 5742.30 5819.78 5897.63 5975.76 6053.45 6133.78 6209.08 6287.50 6371.00 6450.17 E/~V - ft -- -1251.96 -1276.03 -1299.29 -1321.81 -1344.53 -1367.78 -1390.72 -1413.50 -1437.45 -1465.33 -1495.32 -1527.12 -1560.02 -1595.04 -1632.08 -1671.30 -1711.15 -1753.59 -1796.46 -1841.89 -1888.39 -1936.15 -1984.22 -2030.91 -2077.59 -2125.86 -2176.75 -2231.36 -2288.81 -2346.57 -2406.62 -2464.83 -2523.93 -2581.38 -2637.74 -2694.58 -2750.18 -2805.08 -2861.09 -2917.82 -2976.71 -3034.43 -3091.77 -3148.28 -3203.41 -3258.10 -3311.25 -3364.68 -3413.85 -3466.54 -3524.02 -3578.24 AlapN ft 6006668.45 6006717.86 6006767.78 6006817.36 6006866.52 6006915.60 6006965.08 6007014.62 6007063.49 6007118.36 6007177.46 6007239.30 6007302.74 6007370.31 6007439.39 6007510.77 6007582.81 6007658.57 6007733.47 6007811.88 6007890.75 6007970.51 6008051.69 6008134.62 6008218.87 6008301.85 6008383.23 6008462.20 6008538.72 6008613.82 6008690.32 6008764.73 6008842.27 6008918.38 6008995.41 6009074.40 6009152.54 6009231.76 6009309.30 6009384.20 6009462.63 6009539.51 6009616.42 6009694.74 6009773.40 6009852.33 6009930.80 6010011.91 6010087.94 6010167.13 6010251.48 6010331.45 hlapE Tool ff 386959.71 MWD+IFR-AK-CAZ-SC 386936.38 MWD+IFR-AK-CAZ-SC 386913.87 MWD+IFR-AK-CAZ-SC 386892.09 MWD+IFR-AK-CAZ-SC 386870.10 MWD+IFR-AK-CAZ-SC 386847.59 MWD+IFR-AK-CAZ-SC 386825.39 MWD+IFR-AK-CAZ-SC 386803.35 MWD+IFR-AK-CAZ-SC 386780.14 MWD+IFR-AK-CAZ-SC 386753.07 MWD+IFR-AK-CAZ-SC 386723.97 MWD+IFR-AK-CAZ-SC 386693.09 MWD+IFR-AK-CAZ-SC 386661.15 MWD+IFR-AK-CAZ-SC 386627.13 MWD+IFR-AK-CAZ-SC 386591.13 MWD+IFR-AK-CAZ-SC 386552.98 MWD+IFR-AK-CAZ-SC 386514.21 MWD+IFR-AK-CAZ-SC 386472.90 MWD+IFR-AK-CAZ-SC 386431.15 MWD+IFR-AK-CAZ-SC 386386.89 MWD+IFR-AK-CAZ-SC 386341.57 MWD+IFR-AK-CAZ-SC 386295.01 MWD+IFR-AK-CAZ-SC 386248.15 MWD+IFR-AK-CAZ-SC 386202.70 MWD+IFR-AK-CAZ-SC 386157.28 MWD+IFR-AK-CAZ-SC 386110.26 MWD+IFR-AK-CAZ-SC 386060.59 MWD+IFR-AK-CAZ-SC 386007.16 MWD+IFR-AK-CAZ-SC 385950.85 MWD+IFR-AK-CAZ-SC 385894.22 MWD+IFR-AK-CAZ-SC 385835.31 MWD+IFR-AK-CAZ-SC 385778.22 MWD+IFR-AK-CAZ-SC 385720.27 MWD+IFR-AK-CAZ-SC 385663.96 MWD+IFR-AK-CAZ-SC 385608.76 MWD+IFR-AK-CAZ-SC 385553.10 MWD+IFR-AK-CAZ-SC 385498.66 MWD+IFR-AK-CAZ-SC 385444.95 MWD+IFR-AK-CAZ-SC 385390.11 MWD+IFR-AK-CAZ-SC 385334.49 MWD+IFR-AK-CAZ-SC 385276.77 MWD+IFR-AK-CAZ-SC 385220.21 MWD+IFR-AK-CAZ-SC 385164.02 MWD+IFR-AK-CAZ-SC 385108.68 MWD+IFR-AK-CAZ-SC 385054.73 MWD+IFR-AK-CAZ-SC 385001.22 MWD+IFR-AK-CAZ-SC 384949.24 MWD+IFR-AK-CAZ-SC 384897.03 MWD+IFR-AK-CAZ-SC 384849.00 MWD+IFR-AK-CAZ-SC 384797.49 MWD+IFR-AK-CAZ-SC 384741.28 MWD+IFR-AK-CAZ-SC 384688.25 MWD+IFR-AK-CAZ-SC _ ___ __ __ Date: 4/10/2006 "time: 1313:56 Rage: 3 j Co-ordinatc(NE) Reference: Well: CD3-111, True North ' Vertical (TVD) Reference: CD3-111 L1: 49.4 Section (VS)Reference: Well (O.OON,O.OOE,328.59Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Sys 7~VD - ~ --- 5585.96 5664.52 5742.64 5821.24 5900.10 5978.72 6057.35 6136.20 6212.10 6287.95 6357.65 6423.35 6485.51 6545.22 6600.27 6650.89 6697.26 6741.36 6779.72 6814.45 6843.93 6866.75 6881.01 6888.99 6894.71 6899.88 6904.91 6907.20 6906.25 6904.35 6902.46 6899.40 6895.52 6892.55 6890.59 6888.33 6884.41 6879.02 6874.59 6871.16 6867.42 6865.67 6863.34 6860.01 6858.97 Halliburton Compan Global Report -_ ___ Company: ConocoPhillips Alaska Inc. Field: Colville River Unit Site: Alpine CD3 Well: CD3-111 j W'ellpath: CD3-111 L1 Survc~~ - __ -- I~ Mll Incl ft F ~. _- de g _ - - 11504 .26 90 .51 j 11599 .88 89 .89 11695 .66 89 .70 11791 .18 91 .43 11885 .52 91 .12 11981 .51 91 .24 12077 .12 91 .00 ~ 12172 .62 90 .57 12267 .79 89. 08 12363 .56 88. 65 12457 .58 89. 64 I 12553 .19 91. 62 ~ 12648 .95 90. 32 12744.86 12837.92 12936.18 13030.95 13127.14 91.12 89.89 91.12 89.70 88.84 13222.97 13317.93 13412.80 13504.27 13604.13 13698.62 13795.22 13889.52 13985.03 14080.33 14176.56 14190.00 14246.68 14342.41 14438.06 14533.20. 14628.58 14723.95 14818.58 14914.43 15010.15 15105.62 15201.56 15297.19 15392.87 15488.72 15584.51 15680.11 15775.27 15870.94 15965.83 16061.15 16155.28 16251.99 16347.39 91.18 92.42 91.49 91.49 92.36 92.54 91.43 91.62 92.36 91.92 89.95 90.13 86.96 87.64 90.05 90.11 90.54 88.94 90.48 89.93 90.42 89.56 90.30 89.80 89.87 88.63 89.43 89.25 90.05 89.43 90.61 91.29 91.22 91.53 93.01 __ _ - - ~ _ Date: 4/10/2006 Time: 13:13:56 Pater. 4 Co-ordinatc(1VE) Reference: Well: CD3-111, True North ~'crtical (T~'D) Reference: CD3-111 L1: 49.4 Section (VS) Reference: Well (O.OON,O.OOE,328.59Azi) Survey Calculation Method: Minimum Curvature Db:_ Oracle lzim TVD Sys TVD N/S E/W deg ft ft ft ft 326. 90 6912 .84 6863. 44 6529 .28 -3631 .17 324. 26 6912 .51 6863. 11 6608 .16 -3685 .21 322. 87 6912 .85 6863. 45 6685 .21 -3742. 09 325. 14 6911 .91 6862. 51 6762 .48 -3798 .22 324. 56 6909 .81 6860. 41 6839 .60 -3852. 52 324. 67 6907 .84 6858. 44 6917 .84 -3908. 10 322. 69 6905 .97 6856. 57 6994 .86 -3964. 71 320. 57 6904 .66 6855. 26 7069 .72 -4023. 98 320. 80 6904. 95 6855. 55 7143 .35 -4084. 28 323. 52 6906. 85 6857. 45 7218 .96 -4143. 01 322. 73 6908. 25 6858. 85 7294 .16 -4199. 43 323. 33 6907. 20 6857. 80 7370 .54 -4256. 92 324. 66 6905. 58 6856. 18 7447 .99 -4313. 20 329. 30 6904. 37 6854. 97 7528 .38 -4365. 45 331. 63 6903. 55 6854. 15 7609 .34 -4411. 32 329. 20 6902. 68 6853. 28 7694 .77 -4459. 82 326. 40 6902. 01 6852. 61 7774 .96 -4510. 31 326. 33 6903. 23 6853. 83 7855 .03 -4563. 59 326. 67 6903. 22 6853. 82 7934 .94 -4616. 48 326. 13 6900. 23 6850. 83 8013 .99 -4669. 00 325. 61 6897. 00 6847. 60 8092 .48 -4722. 20 328. 06 6894. 62 6845. 22 8169 .01 -4772. 22 325. 91 6891. 26 6841. 86 8252 .70 -4826. 59 326. 91 6887. 22 6837. 82 8331 .34 -4878. 82 327. 02 6883. 88 6834. 48 8412. 27 -4931. 45 326. 13 6881. 37 6831. 97 8490. 94 -4983. 37 329. 45 6878. 05 6828. 65 8571. 69 -5034. 24 329. 50 6874. 49. 6825. 09 8653. 73 -5082. 62 332. 21 6872. 92 6823. 52 8737. 75 -5129. 47 332. 86 6872. 91 6823. 51 8749. 68 -5135. 67 331. 54 6874. 35 6824. 95 8799. 79 -5162. 09 328. 94 6878. 86 6829. 46 8882. 80 -5209. 55 327. 28 6880. 79 6831. 39 8963. 98 -5260. 06 323. 26 6880. 66 6831. 26 9042. 16 -5314. 26 322. 47 6880. 11 6830. 71 9118. 19 -5371. 83 321. 89 6880. 55 6831. 15 9193. 53 -5430. 31 324. 31 6881. 03 6831. 63 9269. 19 -5487. 12 322. 90 6880. 68 6831. 28 9346. 34 -5543. 99 __ AIapN - -- RIapE Tool ft ft 6010411.33 384636.52 MWD+IFR-AK-CAZ-SC 6010491.00 384583.67 MWD+IFR-AK-CAZ-SC 6010568.89 384527.95 MWD+IFR-AK-CAZ-SC 6010646.99 384472.99 MWD+IFR-AK-CAZ-SC 6010724.90 384419.85 MWD+IFR-AK-CAZ-SC 6010803.96 384365.46 MWD+IFR-AK-CAZ-SC 6010881.81 384310.01 MWD+IFR-AK-CAZ-SC 6010957.55 384251.87 MWD+IFR-AK-CAZ-SC 6011032.06 384192.69 MWD+IFR-AK-CAZ-SC 6011108.54 384135.10 MWD+IFR-AK-CAZ-SC 6011184.57 384079.83 MWD+IFR-AK-CAZ-SC 6011261.79 384023.49 MWD+IFR-AK-CAZ-SC 6011340.07 383968.38 MWD+IFR-AK-CAZ-SC 6011421.23 383917.35 MWD+IFR-AK-CAZ-SC 6011502.86 383872.70 MWD+IFR-AK-CAZ-SC 6011589.01 383825.49 MWD+IFR-AK-CAZ-SC 6011669.93 383776.20 MWD+IFR-AK-CAZ-SC 6011750.79 383724.14 MWD+IFR-AK-CAZ-SC 6011831.47 383672.46 MWD+IFR-AK-CAZ-SC 6011911.30 383621.13 MWD+IFR-AK-CAZ-SC 6011990.56 383569.12 MWD+IFR-AK-CAZ-SC 6012067.83 383520.26 MWD+IFR-AK-CAZ-SC 6012152.31 383467.15 MWD+IFR-AK-CAZ-SC 6012231.72 383416.11 MWD+IFR-AK-CAZ-SC 6012313.42 383364.70 MWD+IFR-AK-CAZ-SC 6012392.86 383313.96 MWD+IFR-AK-CAZ-SC 6012474.36 383264.31 MWD+IFR-AK-CAZ-SC 6012557.10 383217.18 MWD+IFR-AK-CAZ-SC 6012641.81 383171.60 MWD+IFR-AK-CAZ-SC 6012653.82 383165.58 MWD+IFR-AK-CAZ-SC 6012704.33 383139.91 MWD+IFR-AK-CAZ-SC 6012788.02 383093.70 MWD+IFR-AK-CAZ-SC 6012869.95 383044.41 MWD+IFR-AK-CAZ-SC 6012948.92 382991.40 MWD+IFR-AK-CAZ-SC 6013025.81 382934.98 MWD+IFR-AK-CAZ-SC 6013102.00 382877.64 MWD+IFR-AK-CAZ-SC 6013178.50 382821.97 MWD+IFR-AK-CAZ-SC 6013256.49 382766.27 MWD+IFR-AK-CAZ-SC 322. 31 6880 .39 6830 .99 9422.39 -5602.12 6013333.39 382709. 29 MWD+IFR-AK-CAZ-SC 322. 14 6880 .41 6831 .01 9497.85 -5660.60 6013409.71 382651. 95 MWD+IFR-AK-CAZ-SC 320. 74 6880 .53 6831 .13 9572.87 -5720.40 6013485.61 382593. 29 MWD+IFR-AK-CAZ-SC 321. 34 6880 .44 6831 .04 9647.23 -5780.53 6013560.86 382534. 28 MWD+IFR-AK-CAZ-SC 320. 93 6880 .72 6831 .32 9721.73 -5840.57 6013636.24 382475. 37 MWD+IFR-AK-CAZ-SC 321. 75 6881 .97 6832. 57 9796.56 -5900.44 6013711.96 382416. 63 MWD+IFR-AK-CAZ-SC 323. 82 6883 .59 6834. 19 9872.83 -5958.36 6013789.08 382359. 87 MWD+IFR-AK-CAZ-SC 325. 50 6884 .70 6835. 30 9950.81 -6013.66 6013867.87 382305. 75 MWD+IFR-AK-CAZ-SC 325. 95 6885 .28 6835. 88 10029.44 -6067,25 6013947.29 382253. 35 MWD+IFR-AK-CAZ-SC 325. 52 6885 .71 6836. 31 10108.51 -6121.11 6014027.15 382200. 68 MWD+IFR-AK-CAZ-SC 326. 35 6885 .68 6836. 28 10187.11 -6174.26 6014106.53 382148. 72 MWD+IFR-AK-CAZ-SC 326. 35 6884 .10 6834. 70 10266.45 -6227.07 6014186.64 382097. 11 MWD+IFR-AK-CAZ-SC 326. 63 6882 .04 6832 .64 10344.91 -6279.02 6014265.87 382046. 34 MWD+IFR-AK-CAZ-SC 324. 47 6879 .71 6830. 31 10424.64 -6333.71 6014346.40 381992. 86 MWD+IFR-AK-CAZ-SC 325. 20 6875 .94 6826. 54 10502.56 -6388.61 6014425.13 381939. 14 MWD+IFR-AK-CAZ-SC Halliburton Compan Global Report Company: ConocoPhillips Alaska Inc. Date. 4/10/2006 Time: 13:13:56 Page: 5 ', 'Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD3-111, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-111 L1; 49.4 Well: CD3-111 Section (VS) Reference: Well (O.OON,O.OOE,328.59Azi) I ~~'ellpath: CD3-111 L1 Survey Calculation D4ethod: Minimum Curvature Db: Oracle Survey __ _ JID Incl _ _Azim _ _ T~'D __ Sps 7VD 1/S _ _ E/1V _ _ 11iapN ___ I~IapE __. _ _ Tool_ ft deg i _ deg _ ft _ <-~ ft ft ft ft ft _ _` _ _ --- _~_-- - _ _------ --- __- 16442.11 92.64 324.74 6871.27 6821.87 10580.03 -6442.92 6014503.39 381886.00 MWD+IFR-AK-CAZ-SC 16537.03 94.32 324.34 6865.51 6816.11 10657.20 -6497.88 6014581.37 381832.21 MWD+IFR-AK-CAZ-SC ~ 16606.89 95.92 323.70 6859.27 6809.87 10713.50 -6538.76 6014638.28 381792.18 MWD+IFR-AK-CAZ-SC j 16645.00 95.92 323.70 6855.34 .6805.94 10744.05 -6561.20 6014669.16 381770.20 -PROJECTED to TD ,-~, m-, ;~ a~. 'I 'y~ ~ ~~,5 9 '1. ~i ?a3,yj ~)`. yid ~ ~ , ~, ~ ~ ~ , a { s ~ a ~~ ~~ ~ ~a ~ i~, ~ ~ ~} 1 ~ ~ ~ ~ ~ ~ ~ . e ~ t ~~ ~ ~ ~ ,~ FRANK H. MURKOWSKI, GOVERNOR ~~ _~ ~~ ~~r+ ~* ~~{t~ ~~ ~~ ~~ L~7I~A Oil/ A~D 117 g 333 W. 7TM AVENUE, SUITE 100 COrTSI~iR'QATIOIQ COMI-iISSIOIQ '~/ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvorc~ Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, Fiord Oil Pool, CD3-111 L 1 ConocoPhillips Alaska, Inc. Permit No: 206-042 Surface Location: 3945' FNL, 874' FEL, SEC. 5, T12N, RSE, UM Bottomhole Location: 3848' FNL, 4730' FEL, SEC. 30, T 13N, RSE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced ~i evelopment well. This permit to drill does r~ct A °:rr* vn„ frnm obtaining additional permits or an approval required by law from other governmental QbPncies and does not authorize conducting drilling operations until all other requireu r Prmits and approvals have been issued. In addition, the Commission reserves the ngnt io withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well CRU CD3-111, Permit No 206-030, API 50-103-20526-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ConocoPhillips Alaska, Inc. Colville River Unit, Fiord Oil Pool, CD3-111L1 Permit No: 206-042 Sincerely, Chairman DATED this~day of April, 2006 cc: Department of Fish 8~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~ ~ S ~~~ ~,Z~ ~ ~ ~-~~~c~.~Se~ce~~-ti ~"`i ~ -~-~. ~..~ ~.~~~ filed,. ' "c ~J~„e ate, ~c9c~ ~ STATE OF ALASKA AL• OIL AND GAS CONSERVATION COMMI~N ,~ PERMIT TO DRILL ~`~ 20 AAC 25.005 ~~~~ V MAR 2 2 2006 1a: Type of Work: 1b. Current Well Class: Exploratory ^ Development Oil 0 1c. Specify if well is pro ®$: t a3 0f13. Oftiriil$$ Drill Q Redrill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas H~~t~f~CBQ~ Re-entry ^ Multiple Zone ^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: Blanket ~ Single Well ^ 11. Well Name and Number: ConocoPhillipsAlaska Inc. Bond No. 59-52-180 ~ CD3-111L/ ~b y~/•od 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 ~ MD: 16555 TvD: ggg~ Colville River Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Fiord Nechelik Pool , Y Surface: 3945' FNL, 874' FEL, Sec 5, T12N, R5E, UM ADL 372105, 364471, 364470 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4705' FNL, 442' FEL Sec 31, T13N, R5E, UM (per original permit) LAS21122 3/21/2006 Total Depth: 9. Acres in Property: 14. Distance to Nearest 3848' FNL, 4730' FEL Sec 30, T13N, R5E, UM (per original permit) " 3180 ' Property: 3890' to CRU boundary 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well 4 ~ ~ (Height above GL): 36.7 feet Within Pool: CD3-110 2067' at 10400' y- 6003828.9 Zone- Surface: x• 388169 16. Deviated wells: Kickoff depth: 14190 ~ feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.6 degrees Downhole: 3~ 7g Surface: 2428 ' 18. Casing Program: Specifications Top -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625' 40# L-80 BTC-Mod 2713 37 37 2750 2500 462sx AS Lite & 230 LiteCrete 8.5" 7" 26# L-80 BTC-Mod 9016 37 37 9053 - 6981 250 sx 15.8 ppg G 6.125" 3.5" 9.3# L-80 EUE-Mod 8133 32 32 8165 6980 tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 15073 6903 n/a 15073 6903 n/a Casing Length Size Cement Volume MD TVD Conductor/Structural 114.00 16" Portland cement 114 114 Surface 2,684.00 9-5/8" 40# 391 sx, Allite, 230 sx litecrete 2721 2469 Intermediate 8,623.00 7" 26# 190 sx 15.8 ppg G 8660 6932 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch ^ Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketct^ Seabed Report ^ Drilling Fluid Program^ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: 1 ~~'a,~ ~pFj ~ Date 3/21/2006 22. I hereby certify that the foregoing is true and correct. ~ Contact V. Johnson 907-265-6081 Printed Name ~i,r Chip Alvord Title Alpine Drilling Team Leader ~ ~ 21/2006 Signature - Phone 265-6120 Date 3/ Commission Use Only Permit to Drill !l ~Q~ "d API Number: _ ` Permit App oval /_ ~~ See cover letter for other t i Number: T~ 50- ~D ~'Z(.~5 - ~ Date: + . ,Q remen s. requ 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 sh Other: Samples req'd: Yes^ No 1[~i' Mud log req'd: Ye^ No HZS measures: Yes^ Directional svy req'd: Ye~ No ^ APPROVED BY THE COMMISSION DATE: ~~~ O ,COMMISSIONER ~ a \ ~ }9 Form 10-401 Revised 12/2005 u mit in Dup~ca~ ,~. Yl3/~6 m • C7 CD3-111 L1 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium i BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers Fiord: CD3-111 L1 Procedure i 1. Pull back to +/- 14190' MD and low side sidetrack the well in open hole. 2. Drill 6-1/8" horizontal section to well TD, +/- 16555' MD. (LWD Program: GR/RES/PWD). 3. Circulate the hole clean and pull out of hole. 4. Run 4-%Z, 12.6#, L-80 tubing with SCSSSV, gas lift mandrels, landing nipple, sliding sleeve and packer. Land hanger. 5. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 6. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 7. Circulate tubing to diesel and install freeze protection in the annulus. 8. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 9. Set BPV and secure well. Move rig off. Drillinsl Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. • • DRILLING FLUID PROGRAM Production Hole Section - 6 1 /8" Density 9.0-9.3 ppg PV 10 -15 YP 25 - 30 Funnel Viscosity Initial Gels 10 -15 10 minute gels 12 - 20 API Filtrate HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 9.0 - 9.5 KCL 6 Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. Fiord (CD3) Colville River Field CD3-111 L1 Production Well Completion Plan 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 2721' MD / 2469' ND cemented to surface 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope TOC @ +/- 7729' MD / 6552' ND Top Kuparuk C 8229' MD Packer Fluid mix: 9.4 RRg KCI Brine with 1500' ND diesel cap Updated 03/21/06 Sperry Sun Directional Plan WP02 Completion MD ND Tubing Hanger 32' 32' 4-Y:" 12.6#/ft IBT-Mod Tubing (2 jts) Crossover 3-Y:' 9.3 #/ft EUE-Mod Tubing Camco TRMAXX-SE SSSV (2.812" ID) 2145' 2000' 3-'/~' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 3839' 3400' 3-Y:' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 6501' 5600' 3-''/:' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 7915' 6668' 3-''/z' tubing joints (2) Baker 3-1/2" CMD sliding sleeve 7955' 6689' w/ 2.813" X Profile 3-''/z' tubing joints (2) Baker Premier Packer 8075' 6749' 3-'/i' tubing 1 joint HES XN 2.813" (2.75" NoGo)-64° inc 8155' 6786' 3-1/2" 10' pup joint WEG 8165' 6786' Baker Premier Packer at +/_ 8075' MD +/- 200 ND above Nechelik Well TD at 16555' MD / ~ 6891' ND 7" 26 ppf L-80 BTC Mod Production Casing @ 8660' MD 16932' ND @ 90° ~ • CD3-111 L1 PRESSURE INFORMATION (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling in MD/TVD ft lbs. / al si si 7" 9053 / 6981 16.0 3158 ~ 2429 N/A 16555 / 6891 16.0 3118 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP=[(FGx0.052)-0.1]D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1084 - (0.1 x 2500') = 881 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2500 = 1635 psi OR ASP =FPP - (0.1 x D) = 3158 - (0.1 x 6981) = 2460 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3118 - (0.1 x 6891') = 2429 psi ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 1 -Rig: CD3-111 Plan: CD3-111 Plan: CD3-111wp05 (sidetrack) Proposal Report 20 March, 2006 ~ ~ _ -._ Sperry Drilling Services r ` Caleulalion Matted: Minimu Error Syatam: ISC9J5 COCIOCOPhI~~I~JS Su"""""°' Trw.~`"°"""'° Colville River Unit Erro<sanaoa: Euiplwiconi~ f~laska warning Mattwd: Ixulaa eased OeadNlo Datum: NM 19P7 (NADCON CONUS) Alpine C D 3 Maprrolk Model: BDOM7905 1 -Rig: CD3-111 C D 3 - 111 w p 0 5 MALLIBURTON Ground Level: 13.30 Plan: CD3-111 S ort DAllln S~Mus RK&. Planned Doyon 19 (d~ 49.60H (Doyon 19 (36.3 ~ 13.31) p y q Northing/ASP V 6003828.92 C D 3-111 wp05 11000 ~ Q ,~ 6-1/8" Open Hole Gp~ TD at 16550.00 ~ 10000 9000 Start Hold 2032.80 Start DLS 4 TFO -90, 14397' MD, 6880' ND t Start DLS 4 TFO -90, 14280' MD, 6875' ND Start DLS 4 TFO -20, 14305' MD, 6677' ND 8000 Kick-off Point; 4° DLS, -150° TFO, 14180' MD, 6872' ND Tie-in Point; 14176.56' MD, 6872.92' ND, CD3-111 P61 7000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 West - /East + 1000 ft/in 6000 Tie-in Point; 14176.56' MD, 6872.92' ND, CD3-111 P81 Kickoff Point; 4° DLS, -150° TFO, 14180' MD, 6872' ND C Start DLS 4 TFO -90, 14280' MD, 6875' ND 0 6500 Start DLS 4 TFO -20, 14305' MD, 6877 ND ~ Start DLS 4 TFO -90, 14397 MD, 6880' ND L ~+ Q Start Hold 2032.80 TD at 16550.00 ~ 4 ~ 6-1/8" Open Hole U 7000 0 w v o /~~ W (n L L r I 7500 _ _ , 9500 10000 10500 11000 11500 12000 12500 ~ / ~ ConocoPhillips ~Uaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Weil: 1 -Rig: CD3-111 Wellbore: Plan: CD3-111 Design: CD3-111wp05 Sperry Drilling Services MAI.LI BURTON Planning Report -Geographic -------- -----__.__.__,__.___ _. Sperry Drlllirtg Senrlcea Local Co-ordinate Reference: Well 1 -Rig: CD3-111 TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) North Reference: True Survey Calculation Method: .Minimum Curvature Project ColviAe River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Leve! Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Weli 1 -Rig: CD3-111 Well Position +N/-S 0.00 ft Northing: 6,003,828.92 ft Latitude: 70° 25' 09.865" N +E/-W 0.00 ft Easting: 388,169.17 ft Longitude: 150° 54' 39.717" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.30ft Welibore Plan: CD3-111 .Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 3/20/2006 23.48 80.72 57,513 Design CD3-111wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 14,176.56 Vertical Section: Depth From (TVD) +N/-S +E/ W Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 329.59 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFD lft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 14,176.56 89.95 332.21 6,872.92 8,737.75 -5,129.47 0.00 0.00 0.00 0.00 14,180.00 90.00 332.38 6,872.92 8,740.80 -5,131.07 5.15 1.45 4.94 73.61 14,280.00 86.54 330.38 6,875.94 8,828.52 -5,178.93 4.00 -3.46 -2.00 -150.00 14,305.00 86.54 329.38 6,877.45 8,850.11 -5,191.46 4.00 0.00 •4.01 -90.00 14,397.20 90.00 328.12 6,880.24 8,928.88 -5,239.27 4.00 3.76 -1.37 -20.00 14,517.20 90.00 323.32 6,880.23 9,028.00 -5,306.84 4.00 0.00 -4.00 -90.00 16,550.00 ~ 90.00 323.32 6,880.11 ~ 10,658.17 -6,521.27 0.00 0.00 0.00 0.00 3/20/2006 11:47:08AM Page 2 of 4 COMPASS 2003.11 Build 50 ConocoPhiUips Alaska M Database: EDM 2003.11 Single User Db Company:. ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: 1 -Rig: CD3-111 Wellbore: Plan: CD3-111 Design: CD3-111wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: • HALLI BU RTON Sperry Drilling Services Well 1 -Rig: CD3-111 Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) True Minimum Curvature Planned Survey CD3-111wp05 Map Map MD Inclination Azimuth TVD SSTVD +N/S +EI W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) lft) (ft) (ft) (°/100ft) (ft) 14,176.56 89.95 332.21 6,872.92 6,823.32 8,737.75 -5,129.47 6,012,641.78 383,171.61 0.00 10,132.12 14,180.00 90.00 332.38 6,872.92 6,823.32 8,740.80 -5,131.07 6,012,644.85 383,170.05 5.15 10,135.55 Kick-off Point; 4° DLS, -150° TFO, 14180' MD, 6872' TVD 14,200.00 89.31 331.98 6,873.04 6,823.44 8,758.49 -5,140.40 6,012,662.67 383,160.99 3.99 10,155.53 14,280.00 86.54 330.38 6,875.94 6,826.34 8,828.52 -5,178.93 6,012,733.27 383,123.51 4.00 10,235.44 Start DLS 4 TFO -90, 14280' MD, 6875' TVD 14,300.00 86.54 329.58 6,877.15 6,827.55 8,845.81 -5,188.92 6,012,750.70 383,113.78 4.00 10,255.40 14,305.00 86.54 329.38 6,877.45 6,827.85 8,850.11 -5,191.46 6,012,755.04 383,111.31 4.00 10,260.39 Start DLS 4 TFO -20, 14305' MD, 6877' TVD 14,397.20 90.00 328.12 6,880.24 6,830.64 8,928.88 -5,239.27 6,012,834.51 383,064.69 4.00 10,352.52 Start DLS 4 TFO -90, 14397' MD, 6880' TVD 14,400.00 90.00 328.01 6,880.24 6,830.64 8,931.25 -5,240.75 6,012,836.91 383,063.25 3.92 10,355.32 14,500.00 90.00 324.01 6,880.23 6,830.63 9,014.14 -5,296.65 6,012,920.62 383,008.60 4.00 10,455.11 14,517.20 90.00 323.32 6,880.23 6,830.63 9,028.00 -5,306.84 6,012,934.62 382,998.61 4.01 10,472.21 Start Hold 2032.80 14,600.00 90.00 323.32 6,880.23 6,830.63 9,094.40 -5,356.31 6,013,001.75 382,950.15 0.00 10,554.52 14,700.00 90.00 323.32 6,880.22 6,830.62 9,174.59 -5,416.05 6,013,082.82 382,891.62 0.00 10,653.92 14,800.00 90.00 323.32 6,880.21 6,830.61 9,254.78 -5,475.79 6,013,163.90 382,833.09 0.00 10,753.32 14,900.00 90.00 323.32 6,880.21 6,830.61 9,334.98 -5,535.53 6,013,244.97 382,774.57 0.00 10,852.72 15,000.00 90.00 323.32 6,880.20 6,830.60 9,415.17 -5,595.27 6,013,326.04 382,716.04 0.00 10,952.12 15,100.00 90.00 323.32 6,880.20 6,830.60 9,495.36 -5,655.02 6,013,407.11 382,657.51 0.00 11,051.53 15,200.00 90.00 323.32 6,880.19 6,830.59 9,575.56 -5,714.76 6,013,488.18 382,598.98 0.00 11,150.93 15,300.00 90.00 323.32 6,880.19 6,830.59 9,655.75 -5,774.50 6,013,569.26 382,540.45 0.00 11,250.33 15,400.00 90.00 323.32 6,880.18 6,830.58 9,735.94 -5,834.24 6,013,650.33 382,481.93 0.00 11,349.73 15,500.00 90.00 323.32 6,880.17 6,830.57 9,816.14 -5,893.98 6,013,731.40 382,423.40 0.00 11,449.13 15,600.00 90.00 323.32 6,880.17 6,830.57 9,896.33 -5,953.72 6,013,812.47 382,364.87 0.00 11,548.53 15,700.00 90.00 323.32 6,880.16 6,830.56 9,976.52 -6,013.46 6,013,893.55 382,306.34 0.00 11,647.94 15,800.00 90.00 323.32 6,880.16 6,830.56 10,056.72 -6,073.21 6,013,974.62 382,247.81 0.00 11,747.34 15,900.00 90.00 323.32 6,880.15 6,830.55 10,136.91 -6,132.95 6,014,055.69 382,189.28 0.00 11,846.74 16,000.00 90.00 323.32 6,880.15 6,830.55 10,217.10 -6,192.69 6,014,136.76 382,130.76 0.00 11,946.14 16,100.00 90.00 323.32 6,880.14 6,830.54 10,297.30 -6,252.43 6,014,217.84 382,072.23 0.00 12,045.54 16,200.00 90.00 323.32 6,880.13 6,830.53 10,377.49 -6,312.17 6,014,298.91 382,013.70 0.00 12,144.94 16,300.00 90.00 323.32 6,880.13 6,830.53 10,457.68 -6,371.91 6,014,379.98 381,955.17 0.00 12,244.35 16,400.00 90.00 323.32 6,880.12 6,830.52 10,537.88 -6,431.65 6,014,461.05 381,896.64 0.00 12,343.75 16,500.00 90.00 323.32 6,880.12 6,830.52 10,618.07 -6,491.39 6,014,542.13 381,838.11 0.00 12,443.15 16,550.00 - 90.00 323.32 6,880.11 6,830.51 10,658.17 -6,521.27 6,014,582.66 381,808.85 0.00 12,492.85 TD at 16550.00 - 6-1/8" Open Hole 3/20/2006 11:47:08AM Page 3 of 4 COMPASS 2003.11 Build 50 ~ ~- ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska inc. Project: Colville River Unit Site: Alpine CD3 Well:. 1 -Rig: CD3-111 Welibore: Plan: CD3-111 Design: CD3-111wp05 Sperry Drilling, Services HALLIBURTON Planning Report -Geographic -~~----~---- -----~----------~- Sperry Drilling Services Local Co-ordinate Reference: .Well 1 -Rig: CD3-111 ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (..) (..) 2,721.00 2,469.32 9-518 12-1/4 8,659.91 6,932.17 7 8-3/4 16,549.99 6,880.11 6-118 6-1/8 3/20/2006 11:47.•08AM Page 4 of 4 COMPASS 2003.11 Build 50 FW: CD3-111 EOW 3D View • Subject: F'W: CD3-111 BOW 3D Vie~~~ From: "Johnson, Vern" Vern..Johnson@conocophillips.com Date: Fri, ?~ 11ar 2006 09:>9:5> -0900 To tone irza~u~der'~i~admin.state.ak.us Tom, See the attached 3-D view of CD3-111. Note that the TD target for CD3-111 L1 plan and the target for the original CD3-111 are the same. o Let me know if you need anything else. Vern 907-260-6081 -----Original Message----- From: Potnis, Brij P Sent: Friday, March 24, 2006 8:52 AM To: Johnson, Vern Subject: CD3-111 EOW 3D View «CD3-111L1 Plan Vs Actual &CD3-111 3DView.pdf» Vern, I couldn't zoom in any closer. Also let me know if the "shadows" don't need to be on the plot. I thought those would help visualize the perspective better. Brij Potnis n .,,~ q CD3-111L1 Plan Vs Actual &CD3-111 3DView.pdf CD3-111L1 Plan Vs Content-Description: Actual &CD3-111 3DView.pdf Content-Type: application/octet-stream '' i Content-Encoding: base64 '; 1 of 1 3/24/2006 10:26 AM ConocoPhillips Al:+ska i-1ALLIEiURTON Sperry Drilling Servicos Protect: Colville River Unk Site: Alpine CD3 Well: CD3-111 Weilkwre: CD3-111L1 Plan: CD3-111 L1 Ground Level: 13.30 RKB: Planned Doyon 19 ~ 49.BOft )Doyon 19 )36.3 ~ 13.3)) Northing/ASP Y: 6003826.92 Fasting/ASP X: 388769,17 CD3-111 L1 • CD3-111 L1 wp05 CD3-111 r~ ti-' ConocoPhillips :11. e;hr ; HALLIBLJRTON Sperry Drilling Services Project: Colville River Unit Site: Alpine CD3 Well: CD3-111 Wellbore: CD3-111L1 Plan: CD3-111 L1 Ground Level: 13,30 RKB: Planned Doyon 19 ~ 49.fi0tt (Doyon 19 (36.3 a 13.3() Norihing/ASP Y: 600J628.92 Farting/ASP X: J88169.17 CD3-111 L1 • CD3-111 L1wp05 CD3-111 • ConocoPhillips Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 21, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-111 L1 '~ Dear Sir or Madam: • Conoco hilli s p ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for a multilateral leg from the main horizontal on the well we are currently drilling, CD3-111L1. After setting 7" intermediate casing, while drilling the 6-1/8" horizontal section the well was drilled deeper in section than planned due to a downhole tool failure. The decision was made to pull out of hole to replace the tools. At that time is was decided to sidetrack the well to keep the well in better quality Nechelik sandstone. r Production is expected from both legs of the well. The well will be sidetracked at +/- 14190' MD and drilled to the originally planned bottom hole target. Note that many of the details in the attached form 10-401 reflect the originally planned depths." Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Vern Johnson at 265-6081, or Chip Alvord at 265-6120. Sinc , 3~2 r~~ Vern Johnson Drilling Engineer • Attachments cc: CD3-111 L1 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Jordan Wiess ATO-1782 Lanston Chin Kuukpik Corporation • • __ _ DELTA BROWN ~~~ ~ ~j~~ 1050 CONOCOPHILLIPS 2Z ` 000 5534 DATE G-tJ 56-1551(441 ANCHORAGE AK //[g7//,01 _ PAY TO TOPE ~ L_ % ~C ,; V J / F/ "L~' ~ ~ Y G`~~ 1.-~WZW~ $ f ~ t~ ~~ ORDER / '• / %~ oe~se.Naa«. ~C; IL G~ G DOLLARS U ~u~'Fea1JfeS 3 l./ J PMorganChase ~ j Valid Up To 5000 D s JPMorgan Chase Bank, N.A. ~j r. Columbus, ~H - .~- '~ -I''J ~ ~ ~ L ~/ J ~~ ~ ~ ~ ~ '`~~~/ V ,~~q~ ~ I MEMO (~ ~YV~ \!~'v^1ti . le-~~1~~~5~-'~ !YP x:044 L L55 L L~:S 2874389886 L911' L050 e • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~b3 ~~~~'G PTD# Zoe _ Q ~Z Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new welibore segment of existing well ~(~ ~ 3 " /~ ' . / V (If last two digits in Permit No. 2D~o • 0,~ API No. 50/D 3 - ~ Suo - Q~~' API number are , , . between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater 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: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: i/25/06 C: \j ody\transmittal_checkl i st a • CI ^ : , , a~ Q a o ; ; ; o ~ ~ ~ _ ~ o - ; ; a A ; ~ ~ y U: rn ~ , o •-, , p a ~ N ~ g ~ ~ . ~ ~ a ~ N y 0 ~ ~ «S v' ~, 3, 4 ~, ~ C N• N, ~ O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N. M Y, ~ fd ~ ~ m , ~ ~ ~ Z 7 ~' ~+ of ~ n. 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O. ~ m m U o' ~ ~, ~', ~, , , a~, m, a o , , 'a~, m, o, ~ ~ U m o U w _ a ~ , , , , , , O N , ~ M I to t0 , , , , _ 00 O O , , , N M V , -, to O~ 00 , , : _ m O N M V , , Ito (D , , , I~ O O O N M ~t tq (p f~- d0 ~ O _ ~ ~ _ N N N N N N N N N N M M M M M M M M M M U U _ _ _ _ ~ - _ ~ o .. d o o N O d I d a~ Q' ~ V O w ^ V IO N C V ~O N ~~ V O ~7'V w O to v a1 V V ) ~ V) . ^ L.L ~ y L .. O _ E N N O rn dJ C7 ~ C E a ~ ~ a~ ~Tj. a m U w a a Q a lL cn Gl ` O. W aF' O ~ G u- acn ; w • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the Tile under APPENDIX. No special effort has been made to chronologically organize this calegory of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 02 08:37:34 2006 Reel Header Service name .............LISTPE Date .....................06/06/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/06/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF ao~ • ~~~ ~ r3g3~ Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: CD3-111 L1 API NUMBER: 501032052660 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-JUN-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004254172 MW0004254172 MW0004254172 LOGGING ENGINEER: R. KRELL R. KRELL R. KRELL OPERATOR WITNESS: D. BURLEY D. BURLEY D. BURLEY MWD RUN 5 JOB NUMBER: MW0004254172 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 5 12N 5E 1334 874 49.40 13.30 OPEN HOLE CASING DRILLERS BIT S K (IN) 1ST STRING 8.750 2ND STRING 6.125 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 9.625 2721.0 7.000 8660.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE CD3-111 WELLBORE AT 14190'MD/6872'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AZIMUTHAL LITHO-DENSITY (ALD), AND GEOPILOT ROTARY-STEERABLE BHA (GP) MWD RUN 2 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND ACOUSTIC CALIPER (ACAL). 6. MWD RUN 5 COMPRISED DIRECTIONAL, DGR, EWR4, PWD, AND GP. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 8. MWD RUNS 1-5 REPRESENT WELL CD3-111 Ll WITH API#:50-103-20526-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16645'MD/6855'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT); 6.25" bit MUD WEIGHT: 9.2 - 9.85 PPG MUD SALINITY: 800 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2697.5 16587.5 NPHI 2700.0 8582.0 NCNT 2700.0 8582.0 FCNT 2700.0 8582.0 RPM 2710.0 16594.5 RPD 2710.0 16594.5 FET 2710.0 16594.5 RPX 2710.0 16594.5 RPS 2710.0 16594.5 PEF 2715.0 14200.0 RHOB 2715.0 14200.0 DRHO 2715.0 14200.0 ROP 2731.5 16645.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2697.5 3 8670.0 4 10657.0 5 14190.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet MERGE BASE 8670.0 10657.0 14190.0 16645.0 Data Reference Point....~......Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2697.5 16645 9671.25 27896 2697.5 16645 FCNT MWD CNTS 578.59 2356.93 1108.04 11765 2700 8582 NCNT MWD CNTS 113105 178216 142951 11765 2700 8582 RHOB MWD G/CM 0.488 3.275 2.40844 22971 2715 14200 DRHO MWD G/CM -3.692 0.331 0.0263956 22971 2715 14200 RPD MWD OHMM 0.2 2000 16.1816 27770 2710 16594.5 RPM MWD OHMM 0.15 2000 13.7633 27770 2710 16594.5 RPS MWD OHMM 0.18 1653.5 11.0383 27770 2710 16594.5 RPX MWD OHMM 0.16 1654.73 9.8122 27770 2710 16594.5 FET MWD HOUR 0.15 70.04 0.946465 27770 2710 16594.5 GR MWD API 25.9 416.6 76.5434 27781 2697.5 16587.5 PEF MWD BARN 0.89 13.4 2.42288 22971 2715 14200 ROP MWD FT/H 0.02 332.52 148.836 27828 2731.5 16645 NPHI MWD PU-S 14.95 59.01 32.4748 11765 2700 8582 First Reading For Entire File..........2697.5 Last Reading For Entire File...........16645 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2697.5 NCNT 2700.0 FCNT 2700.0 NPHI 2700.0 FET 2710.0 RPS 2710.0 RPD 2710.0 RPX 2710.0 RPM 2710.0 PEF 2715.0 RHOB 2715.0 DRHO 2715.0 ROP 2731.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8635.5 8582.0 8582.0 .8582.0 8627.5 8627.5 8627.5 8627.5 8627.5 8595.0 8595.0 8595.0 8670.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 11-MAR-06 Insite 66.37 Memory 8670.0 2731.0 8670.0 32.4 84.1 TOOL NUMBER 149206 96540 1844674407370955 10507541 8.750 2721.0 Fresh Water Gel 9.60 42.0 9.2 850 3.0 2.650 72.0 1.390 143.6 2.350 72.0 1.800 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN):~ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2697.5 8670 5683.75 11946 2697.5 8670 FCNT MWD020 CNTS 578.59 2356.93 1108.04 11765 2700 8582 NCNT MWD020 CNTS 113105 178216 142951 11765 2700 8582 RHOB MWD020 G/CM 0.488 3.275 2.40179 11761 2715 8595 DRHO MWD020 G/CM -2.106 0.178 0.00398852 11761 2715 8595 RPD MWD020 OHMM 0.2 2000 8.30554 11836 2710 8627.5 RPM MWD020 OHMM 0.15 1425.42 5.06877 11836 2710 8627.5 RPS MWD020 OHMM 0.32 987.93 4.8531 11836 2710 8627.5 RPX MWD020 OHMM 0.4 1546.45 4.78834 11836 2710 8627.5 FET MWD020 HOUR 0.15 53.66 0.588251 11836 2710 8627.5 GR MWD020 API 38.48 416.6 114.901 11877 2697.5 8635.5 PEF MWD020 BARN 1.44 12.08 2.91559 11761 2715 8595 ROP MWD020 FT/H 2.28 332.52 179.23 11878 2731.5 8670 NPHI MWD020 PU-S 14.95 59.01 32.4748 11765 2700 8582 First Reading For Entire File..........2697.5 Last Reading For Entire File...........8670 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 • • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RHOB 8595.5 10588.5 PEF 8595.5 10588.5 DRHO 8595.5 10588.5 RPS 8628.0 10607.0 RPD 8628.0 10607.0 RPM 8628.0 10607.0 FET 8628.0 10607.0 RPX 8628.0 10607.0 GR 8636.0 10600.0 ROP 8670.5 10657.0 LOG HEADER DATA DATE LOGGED: 15-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10657.0 TOP LOG INTERVAL (FT) 8670.0 BOTTOM LOG INTERVAL (FT) 10657.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8660.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) 48.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3) 3.2 ~ RESISTIVITY (OHMM) AT ~IP ERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) .300 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .150 155.5 MUD FILTRATE AT MT: .180 72.0 MUD CAKE AT MT: .140 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD030 G/CM 4 1 68 4 2 DRHO MWD030 G/CM 4 1 68 8 3 RPD MWD030 OHMM 4 1 68 12 4 RPM MWD030 OHMM 4 1 68 16 5 RPS MWD030 OHMM 4 1 68 20 6 RPX MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 GR MWD030 API 4 1 68 32 9 PEF MWD030 BARN 4 1 68 36 10 ROP MWD030 FT/H 4 1 68 40 11 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8595.5 10657 9626.25 4124 8595.5 10657 RHOB MWD030 G/CM 0.607 2.94 2.40643 3987 8595.5 10588.5 DRHO MWD030 G/CM -3.692 0.331 0.0198676 3987 8595.5 10588.5 RPD MWD030 OHMM 6.26 2000 38.5788 3959 8628 10607 RPM MWD030 OHMM 1.62 2000 33.1837 3959 8628 10607 RPS MWD030 OHMM 0.18 1653.5 14.7822 3959 8628 10607 RPX MWD030 OHMM 0.16 1654.73 12.1795 3959 8628 10607 FET MWD030 HOUR 0.31 70.04 2.16737 3959 8628 10607 GR MWD030 API 25.9 65.04 49.311 3929 8636 10600 PEF MWD030 BARN 1.08 13.4 2.17659 3987 8595.5 10588.5 ROP MWD030 FT/H 5.36 204.12 114.453 3974 8670.5 10657 First Reading For Entire File..........8595.5 Last Reading For Entire File...........10657 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record.35 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 10589.0 14190.0 RHOB 10589.0 14190.0 DRHO 10589.0 14190.0 GR 10600.5 14190.0 FET 10607.5 14190.0 RPX 10607.5 14190.0 RPS 10607.5 14190.0 RPM 10607.5 14190.0 RPD 10607.5 14190.0 ROP 10657.5 14190.0 LOG HEADER DATA DATE LOGGED: 19-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14190.0 TOP LOG INTERVAL (FT) 10657.0 BOTTOM LOG INTERVAL (FT) 14190.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.6 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 162742 ALD Azimuth. Litho-Den 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 8660.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): Polymer 9.25 42.0 MUD PH: ~ 9.3 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .160 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 162.0 MUD FILTRATE AT MT: .140 68.0 MUD CAKE AT MT: .230 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD040 G/CM 4 1 68 4 2 DRHO MWD040 G/CM 4 1 68 8 3 RPD MWD040 OHMM 4 1 68 12 4 RPM MWD040 OHMM 4 1 68 16 5 RPS MWD040 OHMM 4 1 68 20 6 RPX MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 GR MWD040 API 4 1 68 32 9 PEF MWD040 BARN 4 1 68 36 10 ROP MWD040 FT/H 4 1 68 40 11 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10589 14190 12389.5 7203 10589 14190 RHOB MWD040 G/CM 2.217 3.01 2.42059 7203 10589 14190 DRHO MWD040 G/CM -0.127 0.218 0.0665149 7203 10589 14190 RPD MWD040 OHMM 11.85 50.35 18.353 7166 10607.5 14190 RPM MWD040 OHMM 10.75 56.24 17.6293 7166 10607.5 14190 RPS MWD040 OHMM 10.08 62.64 17.6582 7166 10607.5 14190 RPX MWD040 OHMM 9.01 41.29 15.3243 7166 10607.5 14190 FET MWD040 HOUR 0.3 28.58 1.01027 7166 10607.5 14190 GR MWD040 API 26.59 65.47 45.9376 7180 10600.5 14190 PEF MWD040 BARN 0.89 6.38 1.75732 7203 10589 14190 ROP MWD040 FT/H 1.11 228.99 137.165 7066 10657.5 14190 First Reading For Entire File..........10589 Last Reading For Entire File...........14190 File Trailer Service name .............STSLIB.004 Service Sub Level Name.. Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name........... .STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 14190.5 16594.5 ROP 14190.5 16645.0 GR 14190.5 16587.5 FET 14190.5 16594.5 RPX 14190.5 16594.5 RPM 14190.5 16594.5 RPD 14190.5 16594.5 LOG HEADER DATA DATE LOGGED: 22-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16645.0 TOP LOG INTERVAL (FT) 14190.0 BOTTOM LOG INTERVAL (FT) 16645.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 95.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8660.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 44.0 MUD PH: 9.2 MUD CHLORIDES (PPM): ~ 38000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 165.2 MUD FILTRATE AT MT: .140 72.0 MUD CAKE AT MT: .160 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14190.5 16645 15417.8 4910 14190.5 16645 RPD MWD050 OHMM 1.96 36.98 13.8922 4809 14190.5 16594.5 RPM MWD050 OHMM 2.1 24.85 13.4139 4809 14190.5 16594.5 RPS MWD050 OHMM 1.68 26.19 13.3146 4809 14190.5 16594.5 RPX MWD050 OHMM 1.22 22.11 12.0144 4809 14190.5 16594.5 FET MWD050 HOUR 0.32 67.61 0.727929 4809 14190.5 16594.5 GR MWD050 API 31.86 102.54 49.6757 4795 14190.5 16587.5 ROP MWD050 FT/H 0.02 190.88 119.931 4910 14190.5 16645 First Reading For Entire File..........14190.5 Last Reading For Entire File...........16645 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 • Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/06/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File
