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206-030
• • RECEIVED STATE OF ALASKA MAY 0 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANA0)(16C la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 2 Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 Exploratory LI GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or Lt- 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/22/2017 206-030/317-077/ ' 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 3/6/2006 50-103-20526-00 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 3/19/2006 CD3-111 • Top of Productive Interval: 9.Ref Elevations: KB:4c'..6 17. Field/Pool(s): , 6/ fT 188'FSL, 173'FEL,Sec 31,T13N,R5E,UM GL: (2.q BF: Colville River Field/Fiordeil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 331'FSL, 1566'FWL,Sec 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- ,'3$$itO°I y- l,0038l$ ''''' Zone- 4 15073/6908 ' LAS21122 TPI: x- 3s4.2S. y- ivOCIrt4I Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 382830 y- 3013468 Zone- 4 2130/1994 1270/1244 5.Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A scANNED JUN 0 92017, 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT CASING GRADE FT TOP BOTTOM TOP BOTTOM 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/ND 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 A3 4 .-,, :J-1� 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 .3/Z zit 7- Per 20 AAC 25.283(i)(2)attach electronic and printed information - - DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cs-- Plug Back Cement @ 2521 43.4 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate 7 . Form 10-407 Revised 11/2015 !/T L 4 i/ (TO CONTINUED ON PAGE 2 RBDMS w �1AY L�11 Submit ORIGINIAL onl • 28.CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No El If Yes,list formations and intervals cored(MDITVD, 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 E 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, paleontoloaical reoort.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. `�tfl�t Contact: Marshall Brown A 265-6218 Email: H.Marshall.Brownaconocophillips.com r` kt5 Printed Nam--.T.S- den Title: Well Integrity Intervention Director 1klig Signature: ,� r \ \ Phone: 265-1544 Date: 0/Li INSTRUCTIONS General: This form and\,‘e required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-4'N 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 ND 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 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. • • 4' Cement Detail Report 0.101 0 CD3-111 ConocoPhil lips 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 Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 6 603.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 2,521.0 3,088.0 G 43.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 17.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/10/2017 • perations Summary (with Timelog Depths) 11Jfr . 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,Superintendant 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 • J Iterations Summary (with Timelog Depths) (11-,/ ----',;,32 ,::::aV. 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) 3/11/2017 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 Timelog Depths) .ti CD3-111 ConocoPhitlips 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, 101h 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,Ketch 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 • M Operations Summary (with Timelog Depths) .t,„/„.k2_4_ CD3-111 EN C mcoPhillips 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 4'W 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 y Operations Summary (with Timelog Depths) 6 9 ,a .a g> „ CD3-111 Iv Conoc©Pfialips 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) 3/15/2017 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 f/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. 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 2,921.0 100:00 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. 5/0 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 i • Operations Summary (with Timelog 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) 3/16/2017 3/16/2017 1.00 SLOT PLUG CPBO P Cut 7"Csg @ 2,686'MD w/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 -BORE 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 • • ifoi�vt,„,,4 ,., Operations Summary (with Timelog 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) 3/17/2017 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. R/D 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 w/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 L/D 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 (Aii, „.„,,, ,.x,.,"s, 6, • • Operations Summary (with Timelog Depths) CD3-111 Conoc©Phil 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) 3/18/2017 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/O=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 SIO 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 L/D 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 Operations Summary (with Timelog Depths) ig t'3,Jaa'd 3 , 1: „ , CD3-111 v. 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 UD 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 f/2,512'to 2,608'MD 2,512.0 2,608.0 06:30 07:00 w/3 bpm, 140 psi,P/U=107,S/0= 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 UD 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,S/O= 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 UD Jars,R/B 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 'UD 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 I Page 9/27 Report Printed: 4/10/2017 ilk Ili Operations Summary (with Timelog Depths) CD3-111 ConacoPhillipss 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. R/B 4" 2,703.0 230.0 04:00 06:30 DP. 3/20/2017 3/20/2017 2.00 SLOT PLUG BHAH P L/D 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 L/D 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 • • Operations Summary (with Timelog Depths) 0 CD3-111 44 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) 3/21/2017 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 R/D BOP test equipment and removed 0.0 0.0 07:00 08:00 test plug. Installed 10"ID wear ring I 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 0.0 447.0 112:45 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 • 0 Operations Summary (with Timelog Depths) 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) 3/22/2017 3/22/2017 0.75 INTRMI 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 R/B 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 13/22/2017 3/22/2017 0.50 INTRM1 DRILL DHEQ P Shallow test MWD WI 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 INTRM1 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 yP 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 INTRM1 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 INTRMI 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 INTRMI 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 4., ii; ar * • 0 Operations Summary (with Timelog Depths) CD3-111 ConocoPhil lips if 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 CLEN T Clear and clean rig floor of clay. 0.0 0.0 20:15 20:45 3/23/2017 3/23/2017 1.00 INTRM1 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 INTRM1 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 INTRM1 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 INTRMI 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 INTRM1 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 INTRM1 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 INTRM1 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 INTRM1 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 INTRM1 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 INTRM1 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 • 0 lc Operations Summary (with Timelog Depths) ,ti a. ' 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) 3/26/2017 3/26/2017 6.75 INTRM1 CASING STRP P SOON 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 INTRMI 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 INTRMI 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 SOON 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 LID 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. WI 7"test joint. R/D test equipment and installed 10.25"ID wear ring. 3/27/2017 3/27/2017 1.25 INTRMI 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/0=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 INTRM1 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 INTRM1 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 • • = `` Operations Summary (with Timelog Depths) CD3-111 cfP Conoc©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) 3/28/2017 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 • • Operations Summary (with Timelog Depths) AYfrolr/4-4-1 (4 .ti CD3-111 Con©coPhillips 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 (ttKB) 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'/i'&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/0=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 • • a Operations Summary (with Timelog 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) 3/29/2017 3/29/2017 1.00 INTRM1 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 INTRM1 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 INTRM1 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 INTRM1 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 20:15 20:45 bottoms up @ 200 gpm 1780 psi,80 rpm,8.5k Tq.MW 10.75 ppg in/out. 3/29/2017 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 20:45 21:15 MD @ 200 gpm, 1560 psi. Page 17/27 Report Printed: 4/10/2017 fsF 4,k Operations Summary (with Timelog Depths) CD3-111 ConoccaPhirlips 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, 1l k 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 PPg• 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 • • 40„ Operations Summary (with Timelog Depths) ptv 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) 3/30/2017 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 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,5/0=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 • 6perations Summary (with Timelog 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) 3/31/2017 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 f operations Summary (with Timelog 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) 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,S/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- /bpm 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 0 (# Aerations Summary (with Timelog Depths) i V! NEW,140;146. CD3-111 ConocoPhillip+s 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 4'/"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 • 14,4<r":71,,, Aerations Summary (with Timelog Depths) pre4i 44; 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) 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,R/D 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.S/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/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. 4/4/2017 4/4/2017 1.00 COMPZN 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 4 • • Operations Summary (with Timelog Depths) 444 r-v 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) 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,3'/2'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 • fir " Aerations Summary (with Timelog Depths) 'ezit Ago CD3-111 ConocoPhillips tr 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) 4/5/2017 4/6/2017 8.00 COMPZN RPCOMP PUTB P Continue P/U and run 3W 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/O=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 3'/z'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 4W 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 44444 i f � 4`'° perations Summary (with Timelog Depths) 4111 4F 14, CD3-111 ConocoPhitlips 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 • '� ilperations Summary (with Timelog Depths) tflk CD3-111 ConocoPhil 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) 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 • S 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 3W 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 D • CD3-111 ConocoPhi lips z Well Attribut Max Angle&MD TD Alaski.i in„ Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConocW'hiltip$ ,• 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 CO3-111,5/9/29178:2950 AM SSSV:TRMAXX-5E Last WO: 42.61 3/25/2006 Vertical schematic Ischia]) 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 =m PRODUCTION 7 6.276 34.2 8.660.0 6,932.2 26.00 L-80 BTCM NANGFR.31 0 � � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I 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(ftKB) Set Depth(TVD)...'Wt/Len(I..._Grade Top Thread 7' ' ltc m y>a OPEN HOLE 6 1/8 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 31/2 2.992 31.2 8,159.8 6,788.1 9.30 L-80 8RD EUE Mod N Completion Details I I: Nominal ID ;' FI Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) I f +; 31.2 31.2 0.00 HANGER FMC HANGER W/2.23 PUP 3.958 c l 114.8 114.8 0.50 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 I2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 4/26/2010 2.812 I 8,016.9 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 8,147.9 6,782.9 63.87 NIPPLE HOWCO'XN'NO GO NIPPLE 2.750 CONDUCTOR;38.0-114.0-4 L 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 I001 Top(ftKB) (ftKB) I (°) I Des Com Run Date ID(in) 3,088.0 2,772 1 33.77 CIBP 7"Cast Iron Bridge Plug for Kick Off Cmt. 3/15/20)7 0.000 Stimulations&Treatments Proppan[Designed(Ib) .1Proppant In Formation(Ib) (Date 4/4/2013 Stimulations&Treatments Vol Clean Pump Stg 9I I Top(ftKB) Btm(ftKB) 1 8,660 0 15,073.0 4/4/2013 Date l Stim/Treat Field (bbl) Vol Slurry(bbl) . 1 Proppant Designed(Ib) IProppantln Formation(Ib) 102,000.01 Date 100,000.0 4/13/2017 SAFETY VLv;z,lw.o n,;_I,: Cement Squeezes ISO SLEEVE;2,150.0 Tubing;2,154.3 Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 2,521.0 3,088.0 2,303.1 2,772.1 Cement 3/4/2017 Squeeze I. 7,000.0 7,928.0 6,011.5 6,675.9 Cement 3/4/2017 Squeeze Mandrel Inserts . st atii ° Top(ND) Valve Latch Port See TRO Run SURFACE;36.3-2,721.0 N ) ( ) Type Type (in) (psi) Run Date Com INTERMEDIATE;34.1-8,530.0 . y_ Top(ftKB) (ftKB) Make Model OD in Sery 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 0188 1,730.0 4/5/2013 Cement squeeze;2,521.0ftKB .. .,c. 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 •,alt✓ .. Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L1 f 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;3,846.7 GAS LIFT;6,492.3 - IT 1 Cement Squeeze;7,000.0 ftKB GAS LIFT;7928.8 • <- SLEEVE;8,016.9 PACKER;8,100.9 .._,..., NIPPLE;8,147.9 in WLEG;8,1593 PRODUCTION,2,8200-8,860.0 FRAC;8,680.0 ;+4 L1 WINDOW;14,181.0-14,191.0 J. a 8'C ' OPEN HOLE;8,860.0-15,073.0 4 f 4 4 I, v WNS "OD •CD3-111 L1 COriocooPhilhhpS 4 Well Attribu Max Angle&MD TD Alaska..Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Wm(kKB) Canocaleggi s , 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 CO3-111Ll5/9/20178.21.25 AM SS SV 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)... Wt/Len(i...Grade Top Thread = L1 OPEN HOLE 6 1/8 14,190.0 16,645.0 6,855.3 I HANGER.31.0 •7S Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date all It= 4/4/2013 L 111.::: a Proppant Designed(Ib) Proppant In Formation(lb) Date 100,000.0 102,000.0 4/13/2017 Notes:General&Safety - End Date Annotation r 3/25/2006 NOTE'.MULTI-LATERAL WELL:CD3-111 8 CD3-111L1 ` 4/24/2010 NOTE'View Schematic w/Alaska Schematic9.0 11 . CONDUCTOR,36.0-114.0) lk I SAFETY VLV,2,150.0 -..#:- ISO SLEEVE,2,150.0 - Tubing;2,154.3 SURFACE,36.3-2,721.0 INTERMEDIATE,34.1-8,530.0 Cement Squeeze;2,521.0 ftKB CIBP,3,088.0 GAS LIFT,3,846.7 - GAS LIFT,6.492.3 J A Cement Squeeze;7,000.0 ftKB GAS LIFT;7,9288 SLEEVE,8,016.9 ill PACKER,8,100.9 NM NIPPLE;8,147.9 WLEG;8,159.3 PRODUCTION,2,820.0-8,660.0 . `.? I FRAC;6,66.0 OPEN HOLE,8,660.0-15,073.01 L1 WINDOW,14,181 0-14,191.0 r•r 4 L1 OPEN HOLE;14,190.0- 4 l' 16,645.0 0300 Regg, James B (DOA) From: Alpine Environmental <n1838@conocophillips.com> Sent: Thursday, April 27, 2017 7:46 AM 51Zj1 7 To: DOA AOGCC Prudhoe Bay Subject: Alpine 4/23/17 Spill Report Attachments: 4-27 Agency Report.pdf Hello, Attached is the first and final spill report for a 4/23/17 Alpine spill. This has been completely cleaned up. Please let me know if you have any questions. Thanks, Sam Widmer/ Lynn DeGeorge Alpine Environmental Coordinators ConocoPhillips Alaska, INC. N1838@conocophillipsalaska.com (907) 670-4200 scoop raT 1 CPAI HSE Statistics Databa. • Page 1 of 1 ConocoPhillips Alaska, Inc. First& Final Agency Report Report Date: April 27, 2017 Submitted By: SAM WIDMER SITE OF DISCHARGE: CD3 ADDITIONAL LOCATION INFO: CD3 WELL 111 (.1"t 20(0 TIME OBSERVED: 12:00:00 PM 04/23/2017 INITIAL NOTIFICATION BY: AM HAUNSCHILD TO: ADEC:LAURIE LYONNERBAL-04/23 17:30 ADNR: SPILL REPORTING HOTLINE-04/23 17:38 NSB:LEPC VOICEMAIL-04/23 17:39 Other:AOGCC/ADAM EARL/CALL-04/23 18:14 Other:KUUKPIK/FAX-4/27/7:30 RESPONSIBLE COMPANY: CONOCOPHILLIPS ALASKA TYPE AND AMOUNT: 97.0 Total Gallon(s) — 0.0 Gallon(s)Unto Gravel,covering 0.0 sq ft area 0.0 Gallon(s)Unto Tundra,covering 0.0 sq ft area 0.0 Gallon(s)Into Water,covering 0.0 sq ft area 97.0 Gallon(s) Inside Secondary Containment 0.0 Gallon(s)Into Building 100%DIESEL CAUSE OF DISCHARGE: CORROSION/EROSION CORROSION OF SURFACE CASING. ENVIRONMENTAL DAMAGE: NONE CLEANUP ACTIONS: VAC TRUCK RECOVERED STANDING FLUIDS.NO GRAVEL WAS REMOVED AND EVERYTHING WENT INTO CONTAINMENT. CLEANUP VERIFICATION: VISUAL AMOUNT OF SPILL RECOVERED: 100% CORRECTIVE ACTIONS: INSPECTING AND INSTALLING A PATCH ON THE CASING. DISPOSAL/RECYCLE LOCATION: DISPOSAL AT CD1 FOR CLASS II FLUIDS COMMENTS: REPORTABLE 97 GALLON SPILL OF DIESEL INTO A SECONDARY CONTAINMENT(LINED WELL CELLAR)AT CD3 FROM A DOWNHOLE CASING LEAK. Maximum Oil Storage Capacity of Kuparuk(Gallons):6,930,000(165,000 barrels) Maximum Oil Storage Capacity of Alpine(Gallons): 138,600(3,300 barrels) http //akapps2.conocophillips.net/akstats/AgencySpillRpt.asp?spillId=37010&printerVersi... 4/27/2017 • • Pro a. 06 -6 3 a Loepp, Victoria T (DOA) From: Grimaldi, Louis R(DOA) Sent: Monday,April 24, 2017 1:40 PM To: Quick, Michael J (DOA); DOA AOGCC Prudhoe Bay; Regg,James B (DOA) Cc: Loepp,Victoria T(DOA) Subject RE:CRU CD3-111 Follow Up Flag: Follow up Flag Status: Flagged Yup Sounds like a good plan. Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) Original message From: "Quick, Michael J (DOA)" Date:04/24/2017 13:36(GMT-09:00) To: DOA AOGCC Prudhoe Bay,"Regg,James B(DOA)" Cc: "Loepp,Victoria T(DOA)" Subject: FW: CRU CD3-111 FYI Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.auick@alaska.gov. From: NSK Well Integrity Supv CPF3 and WNS[mailto:n2549@conocophillips.com] Sent: Monday,April 24,2017 1:00 PM To:Quick, Michael J (DOA)<michael.quick@alaska.gov> Subject:CRU CD3-111 Hello Michael- 1 • • I have some details about CD3-111's current state. • The conductor is full of diesel. • The cellar has some diesel in the bottom, but not enough to cover the bottom of the cellar(the cellar is not level, if it were level it might be approximately enough to cover the full bottom of the cellar). On these wells the cellar is a full enclosure, like a giant bucket,where the bottom of the cellar is welded to the outside of the conductor—it provides secondary containment in the wellhouse. • Gas lift is still shut-in • OA has no pressure,there is no active leak Our path forward is to have PTS shut-in the well from the current production flowback and perform a shut-in TIFL. After that,we'll perform a surface casing leak detect. Thanks, Travis Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 • S Loepp, Victoria T (DOA) From: Quick, Michael J (DOA) Sent: Monday,April 24,2017 8:12 AM To: Kanady, Randall B Cc: Regg,James B (DOA); Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Subject: CD3-111 Well Integrity Issue Follow Up Flag: Follow up Flag Status: Flagged Morning Randy— AOGCC inspectors were notified on 4/23 of a release from CD3-111, possibly from a failed OA. Please provide an update on this well to the AOGCC. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.auick@alaska.gov. 1 0 • • co I C a)a)rtoL) no • a)- L) > WrW x to O - C7NZ v v O O N _c 0 JCO O C r b '' > , rD O E On OF��YU d � N > COO_ C p •0 _0Q F 0 (a (n m Q Q < Ix0 0 16 16 16 CO l6 CO N C C C (6 z Q u7 'Q r 01 d > Lr5Z Q 0 C Q Q cc O 0ra) Ou >\ F D 'Q (0 O O 0 0 0 0 0 0 (0 v ,_, s 6 d J J J J J J Ji >• w w w w w w w to C m O F, LL LL LL LL LL LL LL •N 4) E -O N In a Q Q Q Q Q Q Q I2 -0 y0 ru C Z < Z Z Z Z Z Z Z u N 'O N LL LL LL LL u. Ll. LL a) _C `) co a) O O v > r rJ a,C a) O O O ' Z a C -O .-4U w 0 C 0 _0 C O @ 6J QJ 1 ' G O a > > C ' g. .G F 5. '� u _ 1- u) Q v s 0u > '" Lu aa '= JU a - LL G 4) 0 it i6 i D 0 0 CO O MI F U U U a ` ir- d , U ,3 rn > \ C. ril u al al W a) � WV > o o Q g = a M z. Cil 12 t0 0 co w 0 � W I ,► w w w w w w w w W > > > > > > > 2CeWCCLYCert CL z w w w w w w w 0 J J J _J_I J J J w > > > > > > > CLL J J J J J J J C O 0 0 0 0 0 0 U U U U U U U C LU ac a V uJ 06 t0 CO O Cr) O O X / ♦ 0 0 e- ,- 0 co r r o N V z e- o O O O LU u> 0 0 0 0 0 0 0 0 0 0 0 0 0- Q N c o 0 0 0 0 o m LU a ,„::(s a U 6 CC S O O O O O O N N O O O O O O O • N N N CO 0) 0) a+ 0 CO 0) Cr) Cr) 1$) N 0) O) u M r r r Cr) N N to N a N O O O 0 0 0 04, •_ N N NNNNNNN 0' M M M M M M M _E O O O 0 O O O y( • L 0 0 0 0 0 0 0 OO 0 u1 u) )n u) u) v) 111 fa u O0 O _� ,...., ar +'' C O O? u c v v .°. 01 It ✓ QQ W - H Imo{{ r O O O a a C Y Y ` O R7 z N N in e' 0 0 N E a) ...... o Q w U o U DU 0 0 0 £ Z � 0 0 CCM3 of, 0 0 I 1 JFL- a a F • pr0 aoG— 36 Loepp, Victoria T (DOA) From: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Friday, February 24,2017 2:45 PM To: Loepp,Victoria T(DOA) Subject: RE:CRU CD3-111(PTD 206-030, Sundry 317-023) Plug for Redrill -Withdraw this sundry Follow Up Flag: Follow up Flag Status: Flagged Here is the requested email. Please withdraw CRU CD3-111(PTD 206-030)Sundry 317-023 Plug for Redrill as it was replaced with Sundry 317-077. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, February 24,2017 10:40 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]CRU CD3-111(PTD 206-030,Sundry 317-023) Plug for Redrill-Withdraw this sundry Ann, Please reply to this email requesting the subject sundry be withdrawn since it was replaced with Sundry 317-077) Thanx, Victoria \Pik 2 4')(P7 , 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 aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • .-NMI jj,49 THE STATE Alaska Oil and Gas 7,�; �.,etIt Of JL /\ sKA Conservation Commission � r#i_ h, 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 VA, Main: 907.279.1433 finTrn ALAS � Fax: 907.276.7542 www.aogcc.alaska.gov Marshall Brown WOES ` Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CRU CD3-111 Permit to Drill Number: 206-030 Sundry Number: 317-077 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 S DATED this Z Cday of February,2017. RBDMS FEB 2 7 2017 III ECEIV (/,s5° STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 14 2017 APPLICATION FOR SUNDRY APPROVA /°1- . 2-/ ` Oal/1 ? 20 AAC 25.280 GCC 1.Type of Request: Abandon fl Plug Perforations E Fracture Stimulate E Repair Well E Operations Shutdown E Suspend [ Perforate i Other Stimulate Pull Tubing �M: Change Approved Program Plug for Redrill F Perforate New Pool E Re-enter Susp Well I- Alter Casing 1— Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory E Development F • 206-030 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 501032052600 ' 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 F i CRU CD3-111 . 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): 15,073' • 6,908' • 15073 , • 6908 3461psi 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 6,413' 6 1/8 15,073' 6,908' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open Hole 3.500" L-80 8,160' 8660-15073 ' 6932-6908 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER PREMIER PACKER ' MD=8101 TVD=6762 SAFETY VLV-CAMCO TRMAXX-5E-LOCKED OUT 4/26/2010 , MD=2130 TVD=1994 12.Attachments: Proposal Summary 0 Wellbore schematic I] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory I— Stratigraphic E Development F Service E 14.Estimated Date for 2/13/2017 15.Well Status after proposed work: Z Commencing Operations: OIL E WINJ 1 WDSPL E Suspended W 16.Verbal Approval: Date: GAS fl WAG r GSTOR SPLUG E Commission Representative: GINJ E Op Shutdown E 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 c(r7conocophillips.com Printed Name M s all Brown Title Wells Engineer VA, iii'/2.n il— Signature Phone 265-6218 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �,/ � � -; -- - 077 Plug Integrity [[� p �BOP Testg''''''''' ' Mechanical Integrity Test ❑ Location Clearance I=13F- .2-11....I I rJ 1 � i Other: Qd �' ' G j lCti ii 0 p 5--I J D y Post Initial Injection MIT Req'd? Yes ❑ No L? Spacing Exception Required? Yes ❑ Nog Subsequent Form Required: i/9 — 4. 0 - RBDMS Lv FEB 2 7 2017 APPROVED BY Approved by: .'I, COMMISSIONER THE COMMISSION Date: /2. t i 7 �j� A 64NALvalfer / Submit Form ane Form 10-403 eves d 11/2015 � 12 months�froJ7 m 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 stimulatio1.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 o e o cement and abandoned. et/4(V/ i 5/7- 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 BQP 11. Test BOP 3,800 psi Or 12. Pull 3%" produc iot n 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 16"62.54 H-40 Welded 3 Insulated Conductor Permafrost 114'MD/114'ND211/1 "'* ' s C i e .Y.. V. { I 12-''''OH TD 2755'MD f• 3 qtf tk i7- ' '. 9-5/8-4081-80 BTC-M Mud 10.Oppg WBM 4 ( z 'RIP Till431 Surface CasingFt}3v5_ ' { if$ Hc, ?. 2;721'MD/2,469'TVD-- - - ---- - - I Kill Weight Fluid(Brine) #�E 14Irl Gil € ILk , '' !F'M1I I ,�7 I One-Stage Kick-0 Plug I fI c''-` E i)C 2,521 MD/80C 2,920'MD B•E®11•�n el I e P G Ic y M OIIItIIIKl♦!•I•IIII 'CI. tAO-y!r eI 1�� I�I.III iYr3r I ) Sts Iuua�i■1■ 4 3 I Il 5NI . � �•I 'z11 Y'G .:, Immo I !ItiVI iiinuu ui ' ii � ' ., ,I 1I♦I♦iiiiiiiifii 5 iiuiisui • x z;tgaittliA.: :: ::il _l rTiiI. ..... .: - � III1 4 f I S 1 1 Q 15.Bppg Class G Abandonment Plug • I -' _ -_. ' - Top at 7,150'... . .... . Alli ii! ]1 8ii41. ilbli11155510.6160614,-:oilmiqui• .s a I - �• ,,�4� ��„ 7 268 L-80 BTC-M -• .e,' a ` 8'467 MD/6,939'TVD 1111111 ®.. CD3-111A—Rig Workover 5��¢��$4 b �,i 1•,- -'�✓ 6-1/8"OH TD 15,073'MD IIIIIIIIiIIIIIIPIIIIIIIM !:€I 'i=€ 1—Circulate Diesel Freeze Protect Out w/KWF �z�. , �"" ; 2—Remove Tree x'P t:, t ':r ..... 3—Pu II Pre-Cut3-'/: Tubing @3,115'MD �. a "'s 1 :::�€::€ ai = '�'�-" 4—RIH&Set CIBP at"'2,920'MD ?• r . x' S'd k Point @ 14,177'h•^ist��€>I 5-Cut&Pull 7"Casin at ,2910'MD a `.y 6—Sleeve @8,101'MD 7—Cement retainer @8,130'MD Bottom of Cement Plug @ 9,530' Nkhelik 8—Nipple @ 8,148'MD • - OH T D 16,645'MD IIiIiIIII : Sidetrack 61 8 WNS PROD • CD3-111 ConacoPhillips difi n_a Well Attributes Max Angle&MD TD " Alaska:Inc. Wellbore APIIUW1 Field Name Wellbore Status ncl(°) MD(1165) Act Blm(WKB) ,,,,, sips 501032052600 FIORD NECHELIK PROD 93.85 10,073.20 15,073.0 --. Comment 625(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-111,662016 5:09,52 PM SSSV:LOCKED OUT Last WO: 42.61 3/25/2006 Vertical scaemaec(equal) Annotation Depth(10(9) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL/SET WRDP pproven 8/6/2016 Casing Strings Casing Deanlptlon OD(In) ID(In) Top(H65) Set Depth(ttKa) Set Depth(TVD)...Wt/Len(I...Grade Top Thread zr CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded M'15.--'' "l'''' Insulated HANGER;31 2 Casing Description OD(In) ID(in) Top(ft6B) Set Depth(ftKB) Set Depth(TVD)...WULen(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(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(L..Grade Top Thread PRODUCTION 7 6.276 34.2 8,660.0 6,932.2 26.00 L-80 BTCM ��� Casing Description 0D(10) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..-WULen(I...Grade Top Thread Li WINDOW 6 1/2 5.000 14,181.0 14,191.0 6,872.9 + Casing Description OD(In) ID fin) Top(DUB) Set Depth(ftKB) Set Depth(TVD)...W0Len II...Grade Top Thread _ OPEN HOLE 61/8 8,660.0 15,073.0 U i Tubing Strings Tubing Description (Siring Ma...110(in) /Top(ftKB) /Set Depth(ft..Jset Depth(TVD)(...1W1(lb/ft) !Gracie /Tap Connection '`�' x TUBING 31/2 2.992 31.2 8,159.8! 6,788.1 9.30 L-80 8RD EUE Mod CONDUCTOR 34"Insulated: Completion Details 36.0-176.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Mei(') Item Des Corn (In) SO 4.57/35';114.8 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 I2,130.2 1,994.3 38.01 SAFETYVLV CAMCO TRMAXX5E-LOCKED OUT4/26/2010 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 6422 WLFG WIRELINE ENTRY GUIDE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SAFET'VLV;2,130.2 Top(TVD! Top Incl WRDP:2130.0 Top(SINS) (ttKa( (°) Des Com Run Date ID(In) 2,130.0 1,994.1 38.00 WRDP 3 1/2"WRDP W/2.84'PKG(SER HTS-616,98" 8/4/2016 1.250 OAL) Stimulations&Treatments MM Top Max BM Depth Depth Top(TVD) Btm(TVD) (665) (RIM) (ftKB) (MB) Stg N Type Date Com 8,660.0 15,073.0 6,932.2 1 FRAC 4/4/2013 Nechelikformation FRAC pumping 20-bpm,16/20 Carbo Lite Proppant 345,620/I proppent,3041 bbl total.100%of design. Mandrel Inserts SURFACE;06.3.2,721.0- St ati on Top(TVD) Valve Latch Pon Sloe TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Bern 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 . 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 Notes:General&Safety End Date AnnotatIon 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111 5 CD3-111L1 424/2010 NOTE:View Schematic w/Alaska Schemaflc9.0 GAS LIFT;8,492.3 ri GAS LIFT:7.928.8 i_► SLEEVE;0.017.0 11 PACKER;8,100.9 No NIPPLE;8,148.0 '�-_-ja W J•] LEG:8,159.3 i1i- PRODUCTION;34.2-8.960.0 f� FRAC:8,660.0 1 i 1 e LI WINDOW;14,161.0.14,191.0 e I e, OPEN HOLE;8,660.015.073.0 ` • • 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);CD3-111L1(PTD 206-042) Plug for Redrill; CD3-111A(PTD 217-004)Sidetrack: 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);CD3-111L1(PTD 206-042) Plug 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.Gary.Eller@conocophillips.com)<J.Gary.Eller@conocophillips.com>; Bearden,J Daniel (J.Daniel.Bearden@conocophillips.com)<1.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 • Thd plug-for-redrill sundries need 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.Loeppna alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 • 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 al 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, they 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, they 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, they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. . • • El ECEIVED STATE OF ALASKA JAN 18 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon fl Plug Perforations r Fracture Stimulate f Repair Well E Operations Shutdown E Suspend E Perforate r Other Stimulate f Pull Tubing 1 Change Approved Program 1 Plug for Red rill F• Perforate New Pool E Re-enter Susp Well Alter Casing E Other: _ I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory F Development F ' 206-030 • 3.Address: 6.API Numb • - P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 501032052600 • 7.If perforating: '8.Well Name d Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes I No F if CRU CD3-111 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,ADL 364471,ADL 364470 • Colville River F.-Id/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPS• ,- Plugs(MD): Junk(MD): 15,073' ' 6,908' • 15073 - • 6908 04,7 O© NONE NONE Casing Length Size MD V . TVD Burst Collapse Conductor 78' 16" 114' / 1 ' Surface 2,685' 9 5/8 2,721' ,469' Production 8,626' 7" 8,6:,' ` 6,932' Open Hole 6,413' 6 1/8 15,073V 6,908' / Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): Open Hole \1 S ..50 L-80 8,160' 8660-15073 ' 6932-6908 , Packers and SSSV Type: / / Pac rs an SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER / • MD= 101 TVD=6762 SAFETY VLV-CAMCO TRMAXX-5E-LOCKED OUT 4/26/2b10 // \ MD=2130 TVD=1994 12.Attachments: Proposal Summary 0 e�q/ Wellbore s ic p N . . ell Class after proposed work: Detailed Operations Program ❑ BOP Sketch V - "xpl• atory 1.-- Stratigraphic E Development o F Service E 14.Estimated Date for 2/13/20 15.Well Status after proposed work: Commencing Operations: OIL E WINJ E WDSPL I- Suspended 1 16.Verbal Approval: Date: GAS fl WAG E GSTOR r SPLUG E Commission Representative: GINJ E Op Shutdown E Abandoned (' 17.I hereby certify that the foregoing is true and t' procedure approved herein will not be deviated from without prior wri•en approval. Contact Marshall Brown @ 265-6218 Email H.Marshall.Brown a conocophillips.com Printed Name Marshall Brown Title Wells Engineer ,ir L,'Pdf 0-17.01— ` lUrts' ' A n 41. Signature Phone 265-6218 te COMMISSION USE ONLY Conditions of approval: Notify Co, mission so that a representative may witness 'Sundry Number: ,rr� 3‘1— 0 2 Plug Integrity BOP Test�J Mechanical Integrity Test ❑ Location Clearance ❑ Other: ..-4 ; , .D MARI42K17 Post Initial Injection MIT Req'd? Yes ❑ No e 9 Spacing Exception Required? Yes ❑ No g/ Subsequent Form Required: /0 — /0 EVI RBDIVIS \� - 2017 APPROVED BY Approved ��yby: COMMISSIONER THE COMMISSION Date: lilt/it'e LG1 NeArkvalid Subsin Form ane ForForm 10 x03 Revised 11/2015 CA for 12 months from the date of approval. Attachments in Duplicate .s • • 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 CD3-111 ConocoPhillips 1 Well Attributes Max Angle&MO TD A1aSka,ITC. Wellbore API/UWI Field Name Wellbore Statue nal(°) MD(ftKB) Act Bier(6KB) calnei,,,,,ps 501032052600 FIORD NECHELIK PROD 93.85 10,073.20 15,073.0 ••• Comment H25(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date CD3-111,8/6/2018 5:0952 PM SSSV:LOCKED OUT Last WO: 42.61 3/25/2006 Vertical schematic(acluep Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason PULL./SET WRDP pproven 8/6/2016 Casing Strings Casing Description OD(101 ID(In) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded �' '.'"' 4415 Insulated HANGER;31.2 ' Casing Description OD In ID(In) Top ftKB Set Depth(ftKB) Set Depth(TVD)...WULen(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(ftKB) Set Depth(ftKB) -set Depth(TVD)...WULen(...Grade Top Thread PRODUCTION 7 6.276 34.2 8.660.0 6,932.2 26.00 L-80 BTCM Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LI WINDOW 61/2 5.000 14,181.0 14,191.0 6,8729 } t Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread OPEN HOLE 6 1/8 8.660.0 15,073.0 If Tubing Strings Tubing Description String Ma...10(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 'het'TUBING 31/2 2.992 31.2 8159.8 6,788.1 9.30 L-80 8RDEUE Mod CONDUCTOR 34"NWated'._A, i. , Completion Details 36.0114.0 - - --- Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl(°) Item Des Corn (In) XO 4.5.93.5•:114.8 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 H.: 2,130.2 1,9943 38.01 SAFETY VLV 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 2 a{ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SAFETY VLV;2,1302 07) Top(TVD) Top Incl WREN,;3.130.0 Top(ftKB) (11KB) 1°) Dee Com Run Date ID(In) L at i 2.130.0 1,994.1 38.00-WRDP 3 1/2'WRDP W/2.84'PKG(SER HTS-616,98" 8/4/2016 1.250 OAL) Stimulations&Treatments Min Top DepthMax Depth epth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) 01KB) 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 Pmppent.348,6206 proppant,3041 bbl total.100%0l design. SURFACE,36.3-2,721.0-A Mandrel Inserts 1:: St at; Inc• Top(TVD) Valve Latch Port Sloe TRO Run Top(ftKB) (11K13) Make Model OD(In) Dery Type Type (in) (psi) Run Date Corn 1 3,846.7 3,403.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,676.0 4/5/20)3 GAS LIFT;3,846.] 2 6,492.3 5,593.9 CAMCO +KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 ll3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 ili Notes:General&Safety End Date Annotation I 3,2512006 NOTE MULTI-LATERAL WELL:CD3-111&CD3-111L1 4/24/2010 NOTE:View Schematic w/Alaska Schemabc9.0 GAS LIFT,0,4E2.3 - h ✓0i al GAS LIFT.7.928.8 _ SLEEVE.8,017.0 irtA PACKER',8,1009 Q�2/j �( J!/ it I NIPPLE;8,148.0 111 WLEG;8459.3 11 PRODUCTION;34.2.8,880.0 FRAC.8.860.0 '1 4 1 t LI WINDOW,14,181.0-14,191.0 4 4 e,, OPEN HOLE;8,660.0-15.073.0 ' 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 Geo gist 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 J 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 Loepp, Victoria T (DOA) From: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Friday, February 24, 2017 2:45 PM To: Loepp,Victoria T(DOA) Subject: RE:CRU CD3-111(PTD 206-030, Sundry 317-023) Plug for Redrill -Withdraw this sundry Follow Up Flag: Follow up Flag Status: Flagged Here is the requested email. Please withdraw CRU CD3-111(PTD 206-030)Sundry 317-023 Plug for Redrill as it was replaced with Sundry 317-077. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, February 24,2017 10:40 AM To: Haggerty-Sherrod,Ann(Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]CRU CD3-111(PTD 206-030,Sundry 317-023) Plug for Redrill-Withdraw this sundry Ann, Please reply to this email requesting the subject sundry be withdrawn since it was replaced with Sundry 317-077) 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.LoepoCa alaska.00v 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 Victoria.Loeoo@alaska.gov 1 STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COM ION 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 E Exploratory ❑ 206-030 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20526-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372105, 364471, 364470 CRU CD3-111 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 15073 feet Plugs measured None feet true vertical 6908 feet Junk measured None feet Effective Depth measured 15073 feet Packer measured 8101 feet true vertical 6908 feet true vertical 6762 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' SCANNED APR 2 1 2016 Surface 2685' 9.625" 2721' 2469' Intermediate Production 8626' 7" 8660' 6932' RECEIVED Liner Perforation depth Measured Depth: Open hole completion 8660'- 15073' MAR 1 7 2016 True Vertical Depth: 6932'-6908 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): 8660'- 15073' 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 E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ 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 Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature 1. q/Lta-se44/41—‘, Phone 265-6579 Date 3 JJ.61 / IvTL 411i/lh, Form 10-404 Revised 5/2015 Aor,--tAl,� RBDMS Lk' MAR 2 1 2016g Only Submit Original • • 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' r' b \ WNS PROD • CD3-111 ConocoPhillips g Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ORB) Act Btm(ftKB) Ccno.,,,,,hpt '.; 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 CD3-111.4/12120151:44:09 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 hipshkf 4/12/2015 Casing Strings Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded - - .."= Insulated HANGER 31 z I ,Illi Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Tap Thread SURFACE 9 5/8 8.835 36.3 2,721.0 2,469.3 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) 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 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NM)... WtlLen(I.. Grade Top Thread L1 WINDOW 61./2 5.000 14,181.0 14,191.0 6,872.9 Casing Description ' 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread ' �. OPEN HOLE 6 1/8 8,660.0 15,073.0 m ,if Tubing Strings ,j Tubing Description String Me...ID(in( Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection .'. -rA TUBING 3 1/2 2.992 31.2 8,159.8 6,788.1 9.30 L80 8RD EUE Mod Completion Details CONDUCTOR 34"Insulated; , , Nominal ID 36.0-114.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(1 Item Des Con (in) 31.2 31.2 0.00 HANGER FMC HANGER W12.23 PUP 3.958 • XO 4.5'x3.9;114.8 114.8 114.8 0.50 XO 4.5'03.5" CROSSOVER 4.5"x3.5" 3.000 2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 4/262010 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 SAFETY VLV;2.130.2 (5• Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) WRDP;2.130.2 ° Top(ND) Top Incl Top(ftKB) (ftKB) (°1 Des Com Run Date ID(in) 2,130.2 1,994.3 38.01 WRDP 3.5"WRDP-1(S/N:HTS-619,OAL=89.75",2.82" 4/11/2015 1.250 PACKING) Stimulations&Treatments Min Top Max Btm I Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,660.0 15,073.0 6,932.2 FRAC 4/1/2013 Nechelik formation FRAC pumping 20-bpm,16/20 Carbo Lite Proppant.345,620#proppant,3041 bbl total.100%of design. SURFACE;36.3-2,721.0- Mandrel Inserts - St ati on Top(ND) Valve latch Port Size TRO Run N Top(ftKB) (ftKB) Make 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 l i 2 6,492.3 5,593.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L1 4/24/2010 'NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6,492.3 C1 GAS LIFT;7,928,8 47 SLEEVE;8,017.0 PACKER;8,100.9- WI L_. NIPPLE;8,148.0 WLEG;8,159.3 11 PRODUCTION; .-34.2-8,660.0 FRAC;8,680.0 r r r x L1 WINDOW;14,181.0-14,191.0 tie at 6. OPEN HOLE;8,660.0-15,073.0 ' STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COM, _SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations f 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 I✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J;. Exploratory r 206-030 3.Address: 6.API Number P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service f 50-103-20526-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL 372105,364471,364470 CRU CD3-111 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 15073 feet Plugs(measured) none true vertical 6908 feet Junk(measured) none Effective Depth measured 15073 feet Packer(measured) 8101 true vertical 6908 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 MAY 152015 SCANNED -J U N 0 12015 Perforation depth. Measured depth: open hole 8660'-15073' AOGCC True Vertical Depth: 6932'-6908' 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 c 12.Stimulation or cement squeeze summary: Intervals treated(measured). 8660'-15073' 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 F7 Exploratory r Development F.r. Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil p Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ 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 Kerry Freedman @ 265-6579 Email Kerry.C.Freedman(a�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature // Phone:265-6579 Date s/I Y I(j RBDMSj MAY 1 5 2015 f A05 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 CD3-111 Conoco hilIips Well Attributes Max Angle&MD TD Alaska,Inc. ` Wellbore API/AM Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(MB) ,,,,,,,r,d,hll,r„ 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 CO3-111,4/122015 144.09 PM SSSV:LOCKED OUT _Last WO: 42.61 3/25/2006 Venal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET WRDP hipshkf 4/12/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded r ) Insulated _ _ HANGER.31.2 , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)... WtlLen(I.. Grade Top Thread �i -� i SURFACE Casing Description 95/8 8.835 36.3 2,721.0 2,469.3 40.00 L-80 BTC OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ■{ }■ PRODUCTION 7 6276 34.2 8,660.0 6,932.2 26.00 L-80 BTCM 1/ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 0...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(ftKB) Set Depth(ND)... Wt/Len(I...Grade 'Top Thread OPEN HOLE 6 1/8 8,660.0 15,073.0 II 1 I ill Tubing Tubing DescStringsription String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection siertvestisisviremeleststi - TUBING 3 1/2 2.992 31.2 8,159.8 6,788.1 9.30 L-80 8RD EUE Mod Completion Details CONDUCTOR 34"Insulated Nominal ID 36.0-114.0 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.2 31.2 0.00 HANGER FMC HANGER WI 2.23 PUP 3.958 XO 4.5"x3.5";114.6 114.8 114.8 0.50 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 4/2612010 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 I 8,148.0 6,782.9 63.87 NIPPLE HOWCO'XN'NO GO NIPPLE 2.750 ll8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 SAFETY VLV;2.130.2 a= Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) '" p WRDP;2.130.2 - -� Top(ftKB) To(ftK(NB)D) Top Teel(°) Des Corn Run Date ID(in) 2,130.2 1,994.3 38.01 WRDP 3.5"WRDP-1(S/N HTS-619,OAL=89.75",2.82" '4/11/2015 1.250 11 PACKING) Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) (kKB) (ftKB) (ftKB) (ftKB) Type Date Corn 8,660.0 15,073.0 6,932.2 'FRAC 4/1/2013 Nechelik formation FRAC pumping 20-bpm,16/20 Carbo Lite Proppant.345,6208 proppant,3041 bbl total.100%of design. SURFACE.36.3-2.721.0-4 4 Mandrel Inserts St ati I on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make 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.3.6467 2 6,492.3 5,593.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,730.0 4/5/2013 Il3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L1 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,6.492.3 gI I I GAS LIFT.7.928.8 g- SLEEVE;8,017.0 II PACKER.8.100.9 - NIPPLE,8.148.0 WLEG,8.159.3 PRODUCTION,34.2-8.660.0 II I FRAC:8.660.0 ,i rr 1$ LI WINDOW;14,181.014,191.0 1 111 k i r OPEN HOLE;8,6600-15073.0 , • 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 file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~(~ ~p - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ,j Q lsl Protect Proofing III 111111 IIIII II III BY: Maria Date: S' O /s/ Scanning Preparation x 30 = + =TOTAL PAGES // (Count does not include cover sheet) BY: _ Maria Date: In l ,~ n ~ ls! Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: _ Maria Date: ~ /5 Q ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancie(((s were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II IIIII ReScanned III IIIII IIIN II III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III III III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALA, _OIL AND GAS CONSERVATION COMMr.,6ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate rOther Scale Inhibition Alter Casing r Pull Tubing r Stimulate-Frac Waiver 1".- , Treatment r r Time Extension Change Approved Program rOperat. Shutdown 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. Development 17 Exploratory r - 206-030 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r ' 50-103-20526-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372105,364471,364470 I CD3-111 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 . 15073 feet Plugs(measured) None true vertical 6908 feet Junk(measured) None Effective Depth measured $ 15073 feet Packer(measured) 8101 true vertical 6908 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 MAR 0 6 2014 Perforation depth: Measured depth: open hole 8660'-15073' AOGCC Vertical Depth: 6932'-6908' SCANNED AUG 1 4 2014 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,8160 MD,6788 TVD RBDMSZAMAY 13 2014 Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 8101 MD and 6762 TVD • SSSV-CAMCO TRMAXX-5E SSSV @ 2130 MD and 1994 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8660'-15073' there was one treatment(see attached summary)for both Treatment descriptions including volumes used and final pressure: laterals-the volumes listed for each lateral reflect the total treatment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 700 359 109 855 270 Subsequent to operation 831 737 140 837 256 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 rw Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND 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 Kerry Freedman @ 265-6579 Email Kerry.C.Freedman@conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signaturek..2 7 Phone:265-6579 Date 3 i 5-11y U� F /fZ /0- Form 10-404 Revised 10/2012 A 67/ Submit Original Only AWNS PROD CD3-111 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/U WI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) 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 CD3-111,10/2320136'.59.20 AM 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 osborl 10/23/2013 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded ••••••. Insulated HANGER,31.2- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/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 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 34.2 8,660.0 6,9322 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L1 WINDOW 6.12 5.000 14,181.0 14,191.0 6,872.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 I OPEN HOLE 61/8 8,660.0 15,073.0 tITubingTUBING Strings jjjI y j1844Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(IbRt) Grade Top Connection 3 1/2 2.992 31.2 8,159.8 6,788.1 9.30 L-80 8RD EUE Mod Completion Details CONDUCTOR 34"Insulatad;"� • , Nominal ID 36.0.114.0 ll Top MB) Top(ND)(ftKB) Top Incl 5) Item Des Com (in) 31.2 31.2 0.00 HANGER FMC HANGER W/2.23 PUP 3.958 X0 4.55 5'.114.8-r" 114.8 114.8 0.50 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 426/2010 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 8,1523 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 WRDP;2,1302 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SAFETY VLV;2,130.2 Top(ND) Top Incl Top(ftKB) (ftKB) 5) Des Com Run Date ID(in) '-i2,130.2 1,994.3 38.01 WRDP 2.81"X-LOCK 8 WRDP-1(SN'.HTS-619) 10/15/2013 1.250 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (11KB) (ftKB) Type Date Com ° 8,660.0 15,073.0 6,932.2 FRAC 4/1/2013 Nechelik formation FRAC pumping 20-bpm,16/20 IL Carbo Lite Proppant.345,620#proppant,3041 bbl SURFACE;36,3.2,721.0 total.100%of design. Mandrel Inserts St ati C on Top(TVD) VaNe Latch Port Size TRO Run 0 No Top(ftKB) (ftKB) Make Model OD(in) sets Type Type (in) (psi) Run Date m GAS LIFT;3,846.7 ea 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 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK ' 0.250 0.0 4/4/2013 Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111&CD3-111L1 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6.492.3 GAS LIFT;7.92E8 E1 SLEEVE,8,017.0 9 PACKER;8,100.9ON NIPPLE;8.148.0El WLEG 8,159.3 !-f PRODUCTION;34.2-8,660.0 FRAC;8,660.0 /I 1 4 Li WINDOW,14.181.0-14.1910 4 4 4 4 k OPEN HOLE;8.660.0-15,073.0 " CD3-111 Scale Inhibition Treatment 2/10/2014—2/11/2014 Job pumped 15:30 2/10 to 17:00 2/11. Non-Aqueous Scale Inhibitor Squeeze: Initial Pressure TBG/IA/OA-750/788/189; LRS Pumped 182 bbls Preflush (145 bbls of LEPD plus 1528 gal WAW5206)at 0.5 BPM, 2650/764/0; LRS pumped 182 bbl Scale Inhibitor(155 bbls 70/30 MEG plus 1147 gal SCW3001WC scale inhibitor)at 0.25 bpm,2600/750/0; LRS pumped 240 bbls crude overflush at 0.25 bpm, 2900/740/0. Intervals treated:8,660'—15,073' 14,190'—16,645' • off° I�//7% IilE STATE 333 West Seventh Avenue t :-!;\'I,12\CR 1 :,R\F. I Anchorage, Alaskc 995C1 3572 Ei,� �uniis MJ Loveland 6 F Well Integrity Project SC OE ConocoPhillips Alaska, Inc. P.O. Box 100360 /' OaCh Anchorage, AK 99510 a© (C) Re: Colville River Field, Fiord Oil Pool, CD3-111 O� Sundry Number: 314-028 Dear Ms. Loveland: 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, Cathy P. oerster Chair DATED this 17 day of January, 2014. Encl. 110.--- • STATE OF ALASKA • AL ,CA OIL AND GAS CONSERVATION COMMIS,...,N li�� APPLICATION FOR SUNDRY APPROVALS .X 20 AAC 25.280 1 PTJ' f t/t 7 l 1 9._. 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approvisa . .'..f"., Suspend E Plug Perforations E Perforate f Pull Tubing r Time Extension E Operational fm Re-enter Susp. n Stimulate f Alter casing E Other:Conductor Extension f 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developmen fv• 206-030• 3.Address: 6.API Number: Stratigraphi r Service r P.O.Box 100360,Anchorage,Alaska 99510 50-103-20526-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? F Will planned perforations require spacing exception? Yes r No CD3-111 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0364471,0364470 . Colville River Field/Fiord 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): 15073 6908 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' , SURFACE 2685 9 5/8 2721' 2469' PRODUCTION 8626 7 8660' 6932' L1 WINDOW 10 6.5 14191' 6873' OPEN HOLE 6413 6.125 15073' 6908' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8660'-15073' ' 6932'-6908' 3.5 L-80 8159 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) WRDP-2.81"X-LOCK&WRDP-1(SN:HTS-619) • MD=2130 TVD=1994 PACKER-BAKER PREMIER PACKER • MD=8101 TVD=6762 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic E Development F. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil F• Gas I-..� WDSPL fl Suspended E 16.Verbal Approval: Date: WINJ r GINJ E WAG l Abandoned f ' Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878Ca�cop.com Printed Name MJ Loveland ,,,,(, Title: Well Integrity Project Signature ,/�7 < --'.1�/ Phone:659-7043 Date 1/11/14 Commission Use Only Sundry Number: 31 1 .0,3 Conditions of approval: Notify Commission so that a representative may witness VV Plug Integrity E BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMSAY 0 9 2014 Spacing Exception Required? Yes 0 No [v/ Subsequent Form Required: /O 0 /L PAPPROVED BY / J/ Approved by: (1 COMMISSIONER THE COMMISSION Date: rove((�� c ti i v li t/Q�r months trom th_ date of approval. Form 10-403(Revised 10/ 012) pp V /"1 1a1�3 I�(��' 1 pp Submit Form and Attachments in Duplicate v1.-/: ///6//1 X1/''1 ,fit/i,��r NS PROD CD3-111 ,kr,' ° ConocoPhillips. Well Attributes Max Angle&MD TD Alaska Inc" `- Wellbore APIIUVA Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) corora°rvmpc 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 CD3-111.10123201365920 AM 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 osborl 10/23/2013 Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread CONDUCTOR 34" 16 15.010 36.0 114.0 114.0 84.00 J-55 Welded Insulated HANGER;31.2-_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread NE SURFACE• Tr 95/8 8.835 36.3 2,721.0 2,469.3 40.00 L-80 BTC - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 34.2 8,660.0 6,932.2 26.00 L-80 BTCM 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(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 8,660.0 15,073.0 Agemeetrosolevalavyaq 0..4--iL Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 31.2 8,159.8 6,788.1 9.30 L80 8RD EUE Mod Completion Details CONDUCTOR 34"Insulated; Nominal ID 36.0-114 o Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.2 31.2 0.00 HANGER FMC HANGER W/2.23 PUP 3.958 xo4.5'o35',t14.6 114.8 114.8 0.50 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 2,130.2 1,994.3 38.01 SAFETY VLV CAMCO TRMAXX-5E-LOCKED OUT 4/26/2010 2.812 f 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 'I 8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 WRDP;2,130.2 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SAFETY VLV;2,130.2 TopTop Incl Top(ftKB) (ftKB)KSI I') Des Com Run Date ID(in) 2,130.2' 1,994.3 38.01 WRDP 2.81"X-LOCK 8 WRDP-1(SN:HTS-619) 10/15/2013 1.250 Stimulations&Treatments Min Top Max Btm + Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 8,660.0 15,073.0 6,932.2 FRAC 411/2013 Nechelik formation FRAC pumping 20-bpm,16/20 Carbo Lite Proppant.345,6208 proppant,3041 bbl .1 10181.100%of design. SURFACE;38.3-2721.0- Mandrel Inserts St a6 C on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Serepe (in) (psi) Run Date m GAS LIFT;3,8467 1 3,846.7 3,403.9 CAMCO KBMG 1 GAS LIFT GLV TyBKType 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 3 7,928.8 6,676.3 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/4/2013 Notes:General&Safety End Date Annotation 3/25/2006 NOTE:MULTI-LATERAL WELL:CD3-111 8 CD3-111L1 [{r� 4/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,6,4923-174 i--.jwl GAS LIFT;7.929 3 I 9 SLEEVE;8,017.0 PACKER;8,100.9alga NIPPLE;8,148.0 WLEri;8,159.3 PRODUCTION;34.2-8,660.0 FRAC;8,660.0 •t•i Ie t Ll WINDOW;14,181.0.14,191.0 4.99k 1 t 3 X. OPEN HOLE;8,660.0-15,073.0 + 1 L i'7 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 10, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-111, PTD 206-030 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ L eland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-111 (PTD 206-030) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-111 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 11". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor STATE OF ALASKA AL(A OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [ Repair w ell r - Plug Perforations L Perforate r - Other ( Alter Casing j"' Pull Tubing E Stimulate - Frac ri Waiver F Time Extension j Change Approved Program EOperat. Shutdow n 1 Stimulate - Other r Re -enter Suspended Well fl 2. Operator Name: ✓ 4. Well Class Before Work: ✓ 5. Permit to Drill Number: '✓ ConocoPhillips Alaska, Inc. Development (✓' Exploratory r 206 -030 3. Address: 6. API Number: ‘' P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50 - 103 20526 - 7. Property Designation (Lease Number): ✓ 8. Well Name and Number: ✓ ADL 372105, 364471, 364470 CD3 - 111 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 15073 feet Plugs (measured) none true vertical 6908 feet Junk (measured) none Effective Depth measured 15073 feet Packer (measured) 8101 true vertical 6908 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 APR 3 0 2013 Perforation depth: Measured depth: open hole 8660'- 15073' `�� True Vertical Depth: 6932' -6908' SCANNE JUL ' 0 O C.. 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 and 6761 TVD SSSV - CAMCO TRMAXX -5E SSSV @ 2130 MD and 1994 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8660'- 15073' MD Treatment descriptions including volumes used and final pressure: ISI =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 I• Service E Stratigraphic r 16. Well Status after work: r Oil ;►� Gas I — VVDSPL E Daily Report of Well Operations XXX GSTOR 1 — WINJ E WAG E GINJ E 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 - 077 Contact Robert Blakney a 265 - 6417 Email Robert.G.BlaknevOconocophillips.com Printed Name ' obert BL. ne Title Completion Engineer Signature � 0 - - Phone: 265 -6417 Date � it J ,-,> RBDMS MAY -1 2013Y ? // /3 ... e . 5 7 ÷ 6 Form 10 -404 Revised 10/2012 Submit Original Only • • 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 RB WNS • CD3 -111 ConocoPhillips 011 Well Attributes Max Angle & MD TD Alaska, h r Wellbore API/UWI Field Name Wellbore Status !nci ( ") MD (ftKB) Act 8tm (ftKB) • p 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 "' SSSV: LOCKED OUT Last WO: 42.61 3/25/2006 Well Canto : - CD3 -111, 4/17/2013936' 10 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Pull FRAC SLV, SET WRDP haggea i 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 ;. CONDUCTOR34" 16 15.010 36.0 114.0 114.0 84.00 J - 55 Welded HANGER, 31 Insulated I -4 : Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd o ,. ' SURFACE 95/8 8.835 36.3 2,721.0 2,469.3 40.00 L-80 BTC µ:.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 342 8,660.0 6,932.1 26.00 L -80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L1 WINDOW 61/2 5.000 14,181.0 14,191.0 6,872.9 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 8,660.0 15,073.0 I` Tubing Strings Tubin Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd TUBIN I 3 1/2 I 2.992 I 31.2 I 8,159.8 I 6,788.1 9.30 L-80 8RD EUE Mod CONDUCTOR Completion Details 34' Insulated, T o Depth 36 -114 (ND) Top Inc! Nomi... 004.5'33.5 ". Top (ftKB) (ftKB) r Item Description Comment ID lin) 115 31.2 31.2 -0.05 HANGER FMC HANGER W/ 2.23 PUP 3.958 114.8 114.8 0.29 XO 4.5 "x3.5" 'CROSSOVER 4.5 "x3.5" 3.000 I 2,130.2 1,994.2 38.01 SAFETY VLV CAMCO TRMAXX-5E - LOCKED OUT 4/26/2010 2.812 8,017.0 6,720.5 59.85 SLEEVE BAKER CMD SLIDING SLEEVE 2.813 8,100.9 6,761.4 62.43 PACKER BAKER PREMIER PACKER 2.875 8,148.0 6 63.87 NIPPLE ' O NI 2.750 WRDP - 1.2.130 = � 1 8, 6,787.9 64.22 WLEG WIRELINE HOWCO'XN ENTRYG G UIDE PPLE 3.000 SAFETY .130 2.130 Othe In H ( Wi re li n e re plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc( - Top (ftKB) (ftKB) ( ") Description Comment Run Date ID (in) 2,130.2 1,994.2 2.81 "X - LOCK & WRDP (S /N: HTS - 686, OAL= 89.5 ") 4/15/2013 1.250 Type Date Comment Stimulations 8,2 Treat m WRDP ents g Bo Nom 1 Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (ftKB) IRKS) SURFACE,_ 38 -2,721 8,660.0 15,073.0 6,932.1 FRAC 4/1/2013 Nechelik formation FRAC pumping 20 -bpm, 16/20 Cabo Lite Proppant. 345,6208 proppant, 3041 bbl , total. 100 % of design. Notes: General & Safety GAS LIFT, End Date Annotation 3.847 3/25/2006 NOTE: MULTI- LATERAL WELL: CD3 -111 & CD3 -111L1 4/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT ._ GAS LIFT, r 929 SLEEVE, 8,017 11 1 PACKER, 8,101 ... ,9TM/.) NIPPLE 8,148 Mandrel Details _. VI Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... U. WIG. 8,159 1 3,846.7 3,403.9 33.14 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,676.0 4/5/2013 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 0.250 0.0 4/4/2013 PRODUCTION, 34.8,660 FRAC, 8.860 11 WINDOW, 14,181 - 14,191 OPEN HOLE, 8,660. 15,073 T 1 D (CD3 -111), 15,073 CD3 -111 Well Work Summary 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 (TR0 =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. 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**. STATE OF ALASKA AL,CA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ("'- Repair w ell F Rug Perforations 1 Perforate Other I✓ Scale Inhibitor Treatment Alter Casing ("" Pull Tubing r Stimulate - Frac [� Waiver r Time Extension i Change Approved Program i Operat. Shutdow n E Stimulate - Other T Re -enter Suspended Well r`°` 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: - ConocoPhillips Alaska, Inc. Development Exploratory r s 206 -030 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic [ Service i 50 103 - 20526 - 00 - gig 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 364471, 364470 CD3 -111 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 15073 feet Plugs (measured) none true vertical 6908 feet Junk (measured) none Effective Depth measured 15073 feet Packer (measured) 8101 true vertical 6908 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 8660'- 15073' c NED APR 19 2013 AOGC4a' True Vertical Depth: 6932'-6908' ab1'M� 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 and 6761 TVD SSSV - CAMCO TRMAXX -5E SSSV @ 2130 MD and 1994 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8660' - 15073' 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 766 1676 321 -- 289 Subsequent to operation 855 2102 527 - 309 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development I✓ - Service E Stratigraphic I 16. Well Status after work: , Oil F Gas E VVDSPL E Daily Report of Well Operations XX GSTOR [— VVINJ r WAG r GINJ r SUSP E 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: none Contact Jack Walker @ 265 - 6268 Email Jack .A.Walkeraconocophillips.com Printed Name Jack Walker Title WNS Production Engineering Supervisor Signature Phone: 265 -6268 Date - 1 IM 20 (3 R MAR 14 2013 d 41/2-) i 3 Form 10 -404 Revised 10/2012 Submit Original Only WNS • CD3 -111 Conoc -- Well Attributes Max Angle & MD TD Alaska. Inc :; Wellbore API /UWI Field Name Well Status !nci (1 MD (ftKB) Act Btm (ftKB) ,.,oconwap -., 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 "' SSSV LOCKED OUT Last WO: 42.61 3/25/2006 Well Conlin: - CD3 -111, 2/25/20131: 43:/0 PM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP haggea 2/14 /2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 42" 16 15.010 36.0 114.0 114.0 84.00 J - 55 Welded HANGER, 31 - ' , Insulated Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd II r , 1 SURFACE 95/8 8.835 36.3 2,721.0 2,469.3 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.2 8,660.0 6,932.1 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd _ WINDOW 61/2 14,181.0 14,191.0 6,872.9 Casing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ® OPEN HOLE 6 1/8 8,660.0 15073.0 Tubing Strings '�. Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 31.2 8,159.8 6,788,1 9.30 L -80 8RD EUE Mod CONDUCTOR Completion Details 42' Insulated, - 36-114 Top Depth � (TVD) Top Inc! Norm._ XO 4.5^03.5 Top (ft6B) (ftKB) (°) Item Description Comment ID (!n) 115 31.2 31.2 -0.05 HANGER FMC HANGER W/ 2.23 PUP 3.958 114.8 114.8 0.29 XO 4.5"x3.5" CROSSOVER 4.5"x3.5" 3.000 2,1302 1,994.2 38.01 SAFETY VLV CAMCO TRMAXX -5E - LOCKED OUT 4 /26/2010 2.812 8,017.0 6,720.5 59.85 SLEEVE BAKER CMD SLIDING SLEEVE 2.813 8,100.9 6,761.4 62.43 PACKER BAKER PREMIER PACKER 2.875 8,148.0 6,782.8 63.87 NIPPLE HOWCO 'XN' NO GO NIPPLE 2.750 WRDP, 2,130 8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 SAFETY VL 0 2'130 1 =� Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc' Top (ftKB) (ftKB) V) Description Comment Run Date ID (!n) 1 2,130.2 1,994.2 38.01 WRDP 2.81 "XX LOCK & 3.5" WRDP (S /N: HTS -614, OAL =91 ") 2/14/2013 1.250 Notes: General & Safety l End Date Annotation 3/25/2006 NOTE: MULTI - LATERAL WELL: CD3 -111 & CD3 -111L1 4/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, 36 -2.721 GAS LIFT. 3,847 GAS LIFT, 6 492 GAS LIFT, r- 929 SLEEVE, 8017- ~ -I PACKER, 8,101 : 28/ NIPPLE,8.148 - Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size 7RO Run e.•- N... Top (ftKB) (ftKB) ( ") Make Model (in) 1 GAS Sery Type Type (in) (psi) Run Date Cont . . WLEG, 8,159 p J I 1 3,846.7 3,403.9 33.14 CAMCO KBMG LIFT DMY SBK... 0.000 0.0 4/24/2006 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, & & 348,660 0 • • I 0 WINDOW, • 14,181 - 14,191 1 • OPEN HOLE. 0 8,660 - 15,073 • .i TD (CD3 -111), • 15,073 • Scale Inhibition Treatment CD3 -111 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. ` V OF 7 • 0 s THE STATE Alaska it and Gas t w 4...7 } _ - 1 1 Ll onservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALAS � Anchorage, Alaska 99501 -3572 0 2 e Main: 907.279.1433 saHNLD WJ R L Fax: 907.276.7542 Robert Blakney L Completion Engineer �� y,, V ��� ConocoPhillips Alaska, Inc. rl P.O. Box 100360 � Anchorage, AK 99510 Re: Colville River Field, Fiord Neechelik Oil Pool, CD3 -111 Sundry Number: 313 -077 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. g Y Y Y Sincerely, P4e3/ Cathy . Foerster Chair DATED this - day of March, 2013. Encl. • STATE OF ALASKA EC l� 2 AI�(A OIL AND GAS CONSERVATION COM•ION FEB 1 4 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A OGC( '� 1. Type of Request: Abandon I""" Rug for Redrill I ...". ...... Perforate New Pool (' Repair well . Change Approved ogram I Suspend r Rug Perforations (" Perforate Pull Tubing j" Time Extension r Operational Shutdown r Re -enter Susp. Well E--- Stimulate (;� , Alter casing I" Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ly . Exploratory E 206 -030 - 3. Address: Stratigraphic F" Service I°" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20526 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I — No RT. CD3 - 111 • 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 ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): ° 15073 6908 "15073' 6908' none none Casing Length Size MD ND Burst Collapse CONDUCTOR 78' 16" 114' 114' SURFACE 2685' 9.625" 2721' 2469' PRODUCTION 8626' 7" 8660' 6932' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 8660' - 15073'- 6932' - 6908' 3.5 L - 80 8160 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER PREMIER PACKER ` MD= 8101 TVD =6761 SSSV - CAMCO TRMAXX -5E . MD= 2130 ND =1994 12. Attachments: Description Summary of Proposal . 14 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch r Exploratory E Stratigraphic I Development #;r • Service 1 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil 9 - Gas 1 WDSPL I — Suspended r 16. Verbal Approval: Date: VVINJ I.... GINJ I — WAG r Abandoned Commission Representative: GSTOR I SPLUG fl 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.BlaknevCa.conocophillips.com Printed Name Robe Blak Title: Completion Engineer Signature Phone: 265 -6417 Date Commission Use Only Sundry Number.3j 13-- 0-77 Conditions of approval: Notify Commission so that a representative may witness ✓ Plug Integrity F BOP Test E Mechanical Integrity Test r Location Clearance L Other: R BDMS MAR 0 5 2013 Spacing Exception Required? Yes ❑ No [✓j Subsequent Form Required: /7 i I C - 4 6 1 7 4 pMM g p E APPROVED BY / Approved by:A p Cd application is va�Q tOr Pn N6nth s from th i]�t� dT val. Date:3 1,3 form 10 -403 (Re ised 10/2012) l�� � / °RIGINAL � ;�O �bmit� r and Attachments in Duplicate �� �� 3 �� �� WNS IIII CD3 -111 ConocoPhillips Well Attributes Max Angle & MD TD Inc, HWellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Alaska. 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 ... - SSSV: LOCKED OUT Last WO: 42.61 3/25/2006 Well Gonna -CD3 -111, 8/16/201212 24 28 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP ninam 8/16/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 42" 16 15,010 36.0 114.0 114.0 84.00 J -55 Welded HANGER, 31 - '' ■ Insulated ^. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I ' - ^:r., s II SURFACE 95/8 8.835 36.3 2,721.0 2,469.3 40.00 L -80 BTC ; 1.111 ::.: "- Casing Description String 0... String ID... To ftKB Set Depth I... Set Depth String Wt... String String Top Thrd 9 P 9 9 P( ) th P P (TVD) ••• 9 9 �- 9 P PRODUCTION 7 6.276 34.2 8,660.0 6,932.1 26.00 L - BTCM c Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • WINDOW 6 1/2 14,181.0 14,191.0 6,872.9 Casing Description String 0... String ID... Top ftKB Set Depth f... Set Depth TVD).. String Wt... String String Top Thrd 9 9 P( ) th P( P (TVD) 9 9 9 P OPEN HOLE 6 1/8 8,660.0 15,073.0 • ' ;•:,, IP Ilk , ,,,, ill Tubing Strings Tubing Description String 0.,. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3 1/2 2.992 31.2 8,159.8 6,788.1 9.30 L -80 8RD EUE Mod CONDUCTOR Completion Details 42" Insulated, 36-114 Top Depth 1 (TVD) Top Inc( Nomi... x04.5•'3.5, / Top (ftKB) (ftKB) CI Item Description Comment ID (in) 115 ( 31.2 31.2 -0.05 HANGER FMC HANGER W/ 2.23 PUP 3.958 114.8 114.8 0.29 XO 4.5 "x3.5" CROSSOVER 4.55(3.5" 3.000 2,130.2 1,994.2 38.01 SAFETY VLV CAMCO TRMAXX -5E - LOCKED OUT 4 /23/2010 2.812 8,017.0 6,7205 59.85 SLEEVE BAKER CMD SLIDING SLEEVE 2.813 8,100.9 6,761.4 62.43 PACKER BAKER PREMIER PACKER 2.875 8,148.0 6,782.8 63.87 NIPPLE HOWCO'XN' NO GO NIPPLE 2.750 WRDP, 2,130 8,159.3 6,787.9 64.22 WLEG WIRELINE ENTRY GUIDE 3.000 SAFETY VLV, N., I '- 2,130 11 � 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! Top (ftKB) (ftKB) I Description Comment Run Date ID (in) 2,130 1,994.2 38.01 WRDP 2.81 "XX LOCK & 3.5" WRDP (S /N: HES 571, OAL =91 ") 8/9/2012 1.250 Notes: General & Safety End Date Annotation i , 3/25/2006 NOTE: MULTI - LATERAL WELL: CD3 -111 & CD3 -111L1 L 4124/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, 38 -2,721 U GAS LIFT, 3,847 GAS LIFT, 6,492 T: GAS LIFT. T.-. 7,929 SLEEVE. 8,017 ; ` I i : '- h : PACKER, 6,101 NIPPLE, 8,148 ill .Mandr Details Top Depth Top Port (ND) Intl OD Valve Latch Sloe TRO Run Stn Top (MB) (ftKB) ( °) Make Model (in) Sere Type Type (inl (psi) Run Date Corn... WLEG, 8,159 l ' 1 3,846.7 3,403.9 33.14 CAMCO KBMG 1 GAS LIFT DMY SBK... 0.000 0.0 4/24/2006 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 6,6762 58.48 CAMCO KBMG 1 GAS LIFT OV SBK... 0.250 0.0 4/22/2006 PRODUCTION, 34-8,660 WINDOW, 14,161- 14,191 OPEN HOLE, 8,660- 15,073 TD (CD3 -111), 15,073 • 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 2nd 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 Toad 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 Ibs 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 Casino 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 9 9 p 9 o p job p p 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 1 /4 mile radius or any other nearby well. RB • • Stimulation Surface Rig -Up = Bleed / Tattle Tale Tank 1C 1 Cr .43 a c > m.� O • Minimum pressure rating on all surface treating lines 10,000 psi 3R• . ter >: • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 2 psi. u . i 8OJ1 dWrd U �Pp Off 1arit `m N 5,-03 — �- - -- Pump Truck Pop -Off 1 ank tTN V J hi 1 -aril' rr.,f Frac Pump hra.z. l'dnp X_3.; -1 Frac Pump RB • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) 19 / FRAC IRON / FRAC IRON TiOti S Jr- 3 ` 4Vt / REMOTE OPERATED a a " I I MASTER VALVE ommosommo MIINIMMIIIIM 1 ali. 0 (( } . MANUAL OPERATED +,f, I € } MASTER VALVE emw4+r �� emetameas ! rr Stinger Stinger I ;PI MANDREL t: ____ IsT ii - '''. .,„ . �, I S. l .F— VALVE .1 `\ k , OPEN fir : I J n c \''-�} �� �' FLOW TEE AND / 1 �f �� % ` VENT VALVE WELLHEAD J' a,4°;;> i lit VALVES ,,.� ARN OPEN ( , v S 1: N. 1 WELLNE,M7 , ten'"$. VALVES � ( / ` � ` 4 CLOSED '�' .! A►. � "' I.I?1i. .+ OVAD PACKOFF w f * ASSEMBLY IN 1 E rrr IV PLACE IN TURING TUBING • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1 /2 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 —„cfni Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. 0 Name Rate Volume Conc.. Type and Mesh Conc.. (bbl/min) (gal) (lb fingall (PPAI Pad 40.0 YF125ST 21840 25.0 0.00 2.0 PPA 40.0 YF125ST 9269 25.0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 17157 25.0 CarboLite 16/20 4.00 4M PPA 40.0 YF125ST 14297 25.0 CarboLite 16,120 4.00 7.0 PPA 40.0 YF125ST 27650 25.0 CarboLite 16/20 7.00 Flush 40.0 WF125 6722 25.0 0.00 Fluid Totals ID 90212 gal of . YF125ST 6722 gal of . WF125 Proppant Totals 337900 lb of CarboLite 1"28 .. 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_______________ 0.407 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. I C D3 -119 CD3 -109 • CD3 -106 ` • CD3 -108 CD3 -106L1 CD3 -110 • 't CD3- 119PB1 :5 r CD3 -301 + CD3 -1Q L1 • CD3 -301A a'' - C D3- 301PB1 e •CD3 -11 " CD3�107 • • FIORD Or -- CD3 -113 Le • • • Well - Suspended CD3- 301APB1 P +A • Service • Producer CD3 -114 • Observation • Injection: SW • • Injection: SAPW I • • Injection: PW • Injection: MWAG • ACTIVE, INJ, MG • ACTIVE, INJ, IWAG • CD3 -115 CD3 -302P • ACTIVE, INJ, GAS • ACTIVE, INJ, DG • ' • ACTIVE, INJ, <Null> • Disposal l • •,, .'.; I • a FracBuffv3 - ,. Well Nam e • Is CD3 -111 f - CD3 -111L1 • 6 p ConocoPhillips Operated Units t• " 'I 2 at Nanuq Nanuq Participating Area °t' ? � ` p, NPR -A boundary : onochilhips <X C -111 a nd CD3 -111 L1 . , . �; `'°�'� Fracture Locations ,.,,, • °a N CONF IDENTIAL . *• ' . .....r_ ...... „,... • . 'r, :t..,. , °ti. •;e is o. zs o.s • • .y ,aar ~ ."S ,,, "�..: >,' Al / � \ t Miles •• i ; i e -. & , =fi ,.•� ° „• + . . ...... . . . .. °' FracProgram2013.mztl CSR 1 -10 -2013 } w ! ~~; ~ - 4 ,. ~ ~~~, MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet.Files\OLK9\Microfilm_Marker.doc • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • APF~ ~ 2Q0~ 5~70~` fi (lr'. , C~3' X11 Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped Apri15~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060300 Well Name/No. COLVILLE RIV FIORD CD3-111 Operator CONOCOPHILLIPS ALASKA INC MD 15073 TVD 6908 Completion Date 3/25/2006 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20526-00-00 UIC N REQUIRED INFORMATION i J Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name D D Asc Directional Survey ED/C Lis 15011 ~'(nduction/Resistivity Rpt~ LIS~Verification ~+'ED C TIF 13938+~Ifiduction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORM A TI ON Well Cored? c ~ ~ Y ~ rv ~ Chips Received? YY ! Analysis `~fid~ Received? Comments: (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No 2-4 Interval OH / Start Stop CH Received Comments 36 15073 Open 6/27/2006 _ 2697 15073 Open 4/17/2007 LIS Veri, GR, NCNT, CPHI, GET, RHOB, DRHO, ROP w/Graphics CGM, EMF, PDF Open 6/8/2006 LIS 2697 15073 Open 6!8/2006 GR, NCNT, NPHI, RHOB, ROP Sample Interval Set Start Stop Sent Received Number Comments Compliance Reviewed By: __ ___ - _._________ Daily History Received? ~N Formation Tops ~ / N Date: CD3-111 (PTD 2060300) Rep~of SSSV repair ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophitlips.com] Sent: Thursday, May 08, 2008 2:33 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; NSK Prod Engr Tech Subject: CD3-111 (PTD 2060300) Report of SSSV repair Jim, On 05/07/08, Slickline brushed and flushed the SSSV and got a passing closure test following the work. After a passing closure test, the well was returned to production. The well will be added to the SVS misc. list for May. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 5/15/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-030 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-111 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20526-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ^~ 307-066 2/21/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352" 352 totals (bbls): 2oo7/1st 9654 100 0 9754 9 3/21/2007 3/31/2007 CD3-114 2007 / 2nd 16653 100 0 16753 15 4/1/2007 4/20/2007 CD3-114, CD3-301 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th volume 26307 200 352 26859 24 Ex: of the month following the final month of the quarter (bbls>: . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "freeze rotect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ( Date: ~( ~~ la a Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 r Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-030 ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD3-111 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20526-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 307-066 2/21/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352" 352 totals (bbls): 2007 / 1st 9654 100 0 9754 9 3/21/2007 3/31/2007 CD3-114 2007 / 2nd 16653 100 0 16753 15 4/1/2007 4/20/2007 CD3-114, CD3-301 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th volume 26307 200 352 26859 24 (bbls>: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeZe protect volumes I hereby certify that the foregoin 'true and correct to the best of my knowledge. Signature: l ~ Date: (~~ ~~ z3 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-O~U ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD3-111 2. Address: 4b. Well Status: Oil ^Q Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20526-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation 0 or Final ~ 307-066 2/21/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): 2007 / 1st 9654 100 0 9754 9 3/21/2007 3/31/2007 CD3-114 2007 / 2nd 16653 100 0 16753 15 4/1/2007 4/20/2007 CD3-114, CD3-301 2007 / 3rd 0 0 0 0 0 2007 / 4th Total Ending Report is due on the 20th volume 26307 200 352 26859 24 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): '"freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. //'~ Signature: << ~ ~, Date: l~ ~~ /b ~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 206-030 ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 7. Well Name: CD3-111 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20526-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 307-066 2/21/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): 2007 / 1st 9654 100 0 9754 9 3/21/2007 3/31/2007 CD3-114 2007 / 2nd 16653 100 0 16753 15 4/1/2007 4/20/2007 CD3-114, CD3-301 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 26307 200 352 26859 24 (bbls>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze rotect volumes I hereby certify that the foregoing is true a nd correct to the best of my knowledge. ~ ~ > ~S ~o ~ ` 5 ' - Signature: \ °- --~ Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate WELL LOG TRANSMITTAL To: State of Alaska 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 L1, April 17, 2007 AK-MW-4254172 CD3-111 &CD3-111 L1: LIS & Digital Log Images: 50-103-20526-00, 60 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ j ~~ Date: Signed: -~ ~ ~3S 5. °3tT~1SSiCg f ~~i~' ~~-- 20 ~o - 03 d ~ t5 bl~ ao~ - era fso~a 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 2f~-030 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: .CD3-111 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20526-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 307-066 2/21/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 352* 352 totals (bbls): 2007 / 1st 9654 100 0 9754 9 3/21 /2007 3/31 /2007 CD3-114 2007 / 2nd 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 9654 100 352 10106 9 of the month following the final month of the quarter Ex: (bbls>: . Apri120 for the first quarter July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeZe protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ,r-•..•-_.. ,~~,.,_ Si ~ ~~ ' ~~"'~.%~'L:T `~ ~3>'~ gnature: ---.~ - Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate s~~~tf ~auw, Go~ER~OR ~T~+~1 /~t~8t~. OIL 1~11T~Dr~r~a~~'T 1®~7~I~~~ai®id ~® -7-7~®li Chip Alvord ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-111 Sundry Number: 307-066 Dear Mr. Alvord: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 200 7 Encl. c ~~ ~~ `~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 13, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-111 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-111 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3-111 approximately February 28, 2007. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: CD3-302 (to 9-5/8" casing point) 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations. The initial annular LOT (14.6 ppg) occurred at a lower equivalent mud weight than the casing shoe test (17.4 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FTT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Si ely, ~2 z/ ~/ ~ ~..-^ Vern Johnson Drilling Engineer cc: CD3-111 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 ~~ ,~~~~ i REC~I~/ED ~ ' . STATE OF ALASKA ~ti~\ FEB 1 5 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION Alaska Oil & Gas Cons. Commission 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: Number: 206-030 ConocoPhillips Alaska 4. API Number: 50-103-20526-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-111 ` 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD3-109, CD3-110, CD3-112, CD3-302, CD3-113 Torok and Seabee formation, shale, siltstone and sandstone ~ ~ ~ ~~"'®~ ~1-~ ~ G~~ ~~"~~,~~~ b) Waste receiving zone: b) water wells within one mile: ~ ~ h CE~t..~ t~ti n Sand layers below the C30 marker in the Seabee formation 't'~t.S(>rcc.~w~ ~~-~~ f None c) Con inement: ~~` p'~ ~~ i h l Th h Bl ff f id b i d d l S d ti t y ~~`c~ er an mar ne s es an ra er orma on prov es an upper arr a c ays ones e c u of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1658' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2234 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. ' Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- completion fluids formation fluids associated with the contaminated drilling mud diesel 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 28-Feb-07 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: FIT Records w/LOT Gra h ~ p Well Schematic (Include MD and TVD) Cement Bond Log (if required) ^ Surf. Casing Cementing Data ~ Other ~ ~~Z MC~.~~_\~`~~tti.~C'+~~IT~C~,\. 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Title: Printed Phone ' Name: ,~ Chip Alvord Number: 265-6120 Date: ~(¢( ~ Commission Use Only Conditions of approval: ~C,tw~\<~,~~~ `"~ [ ~j ~~~ ~®~ ~ LOT review and approval: ~~ a `1 °"'`° ~ r ®~~ Subse m re ir e t f d `~ ~'~~ A l b qu n or qu e : er: pprova num APPROVED BY _^_ Approved by: COMMISSIONER THE COMMISSION Date: Z~'~ ~~~~1~~~~ ~i~~~~~~o- ORIGINAL ~ Form 10-403RD Rev. 6/2004 INSTRUCTIONS ON REVERSE 3C7timit~D/u ~~e Annulus Disposal Transmittal Form -Well CD3-111 AOGCC Regulations, 20 AAC 25.080 (b) 1 Desi nation of the well or wells to receive drillin wastes: CD3-111 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2234 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3-107, CD3-302, CD3-113, CD3-301, CD3-115, CD3-114 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rudent. 16 Any additional data required by the commission to confum N/A containment of drillin waste. [aximum Fluid Density to avoid Burst of Surface Casing >urst85% -PHydrostatic +PApplied - PFonnation Version LO - lan'OS ,888 = ( 2,469 * 0.052 * MW~ ) + 1500 - (0.4337 * 2,469 ) MWmax = 34.7 PPg Surface Casing String Size 9.625 in Weight 40 ppf Grade rb~rsa oo°r° Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure L 80 5,750 Pst 4,888 psi 2,469 ft 17.4 ppg or 2,234 psi 14.6 ppg 1,500 psi [aximum Fluid Density avoid Collapse of 2nd Casing String ;ollapse85% -PHydrostatic +PApplied - PGasGradient - PHeader ,599 = ( 6,552 * 0.052 >F MWm~ )+ 1,500 - (0.4570 * 6,552) - 0 MWmax = 17.9 PPg 2nd Casing String Size 7 in Weight 26 ppf Grade rcollapse 100% Pcollapse85% Top of Cement Gas Gradient Max Surf. Pressure Header Press L 80 5,410 psi 4,599 psi 6,552 ft 0.457 psi/ft 1,500 psi 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable -Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,469 * .052 * 17.4 ) Pmax allowable - 2,234 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". psi PPg psi/ft psi/ft psi Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 Maximum density of the injection fluid is 12.0 Pore pressure at the 9 5/8" casing shoe is 0.434 Gas/Fluid Gradient in tubing/casing annulus 0.457 Header Pressure (for wells on gas lift) 0 Well CD3-i l l Date 2/12/2007 ConocoPhilli s p Casing Detail 9 5/8"Surface Casin_g Well: CD3-111 Date: 3/8/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 2.20 36.30 Jts 3 to 70 68 Jts 9-5/8" 40# L-80 BTC Csg 2601.57 38.50 Weatherford Float Collar 1.46 2640.07 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.17 2641.53 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 2718.70 2721.00 TD 12 1/4" Surface Hole 2731.00 12-1/4" Hole @ 2731' MD / 2477' TVD 9-5/8" Shoe @ 2721' MD / 2469' TVD RUN TOTAL 40 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8: 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68 76 joints in the pipe shed. Run 70 joints - 6 joints stay out Use Best-o-Life 2000 i e do e MU torgue _ 9000 ft/Ibs Remarks: Up Wt - 170k Dn Wt - 145k Block Wt - 75k Supervisor.• D. Burley / D. Mickey ~ Cement Detail Report CD3-111 ..,.- Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10103852 3/4/2006 3/6/2006 3/25/2006 - - Cement Details - - Description _ --- - - Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/8/2006 00:00 3/8/2006 00:00 CD3-111 Comment Cement Sta es - - -- - Stage # 1 __ _ Description Objective Top (ftKB) Bottom (ftKB) Full Retum? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary cement 36.0 2,721.0 Yes 106.0 Yes Yes O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 6 610.0 1,100.0 Yes 2 0.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives - __ ---- - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,221.0 410 G 325.4 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 10.70 Additives Additive Type Concentration Conc Unit label - Flud __ - -- Fluid Type Fluid Descnption Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,221.0 2,721.0 G 49.6 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 15.80 Additives Additive Type Concentration Conc Unit label Page 1/16 Report Printed: 12/28/2006 ~- r Security Level: Development Daily Drilling Report CD3-111 Report Number: 5 ,~ ,, . Rig: DOYON 19 Report Date: 3/8/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) CD3-111 Development FIORD NECHELIK 3/6/2006 2.77 2,731.0 2,731.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10103852 6,134.53 48,028.60 441,102.53 929,918.60 5,411,831.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) 9 5/8" Surface Casing, 2,721.OftK6 Ops and Depth ~ Morning Report 24hr Forecast RIH w/ BHA # 2 Drill 8 3/4 hole Last 24hr Summary Finish LD BHA - RU & run 9 5/8" csg to 2721' - Cmt csg - RD cmt &csg equip - RU 8~ test BOPE General Remarks Weather Head Count -31 12 mph -57 WC 48.0 Supervisor Title Dave Burley Rig Supervisor Don Mickey Rig Supervisor Time Log __ - a7 it F ~,, Dur Time n„ oth Stag Depth L ~~a T~~ Ti.~~ nrs) ~ Pnase C n, P-N-T iftKB) {ftKi'~ Comr~C>~- ~,,an I - p ode OpSub Co._ Trbl ( ~~_.__ Trb~ Class. 1 . . _ 00:00 00:45 0.75 SURFAC DRILL PULD P 0.0 0.0 Lay down motor -clear tools from rig floor 00:45 02:30 1.75 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 5/8" casing 02:30 02:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Pre-Job safety and Opts meeting with crew 02:45 06:30 3.75 SURFAC CASING RNCS P 0.0 1,525.0 Make up & Thread lock 9 5/8" Silver bullet float shoe, 2 - jts 9 5/8", 40#, L-80 , BTC casing, 9 5!8" Float collar, Circ and check float equip., RIH with 9 5/8" casing to 1525' (40 jts total) 06:30 07:00 0.50 SURFAC CASING CIRC P 1,525.0 1,525.0 Circ BU, mstage rate up from 3.5 bpm to 5.5 bpm @ 290 psi - PUW 150K SOW 118K -Full returns 07:00 08:30 1.50 SURFAC CASING RNCS P 1,525.0 2,721.0 Continue running 9 5!8" casing to 2,677' (Total 70 jts) - MU FMC GEN V casing hanger and landing jt. -Land casing with shoe @ 2721', FC @ 2,640' 08:30 09:15 0.75 SURFAC CEMENT PULD P 2,721.0 2,721.0 Lay down Frank's fill up toot -blow down top drive -Make up Dowell cement head 09:15 11:00 1.75 SURFAC CEMENT CIRC P 2,721.0 2,721.0 Stage pumps up to 7 bpm / 320 psi - Circ and condition mud for cement job -Held PJSM with all personnel 11:00 13:00 2.00 SURFAC CEMENT DISP P 2,721.0 2,731.0 Pump 40 bbls biozan water w/ nut plug at rate of 6.0 bpm @ 190 psi with rig pump, Swith to Dowell & pump 5 bbls water, Test lines to 3000 psi, Drop btm plug, Mix & pump 50 bbls 10.5 ppg MudPUSH XL at rate of 6.0 bpm @ 540 psi, Mixed & pumped 325 bbls (410 sxs) 10.7 ppg Lead slurry plus additives at rate of 7.5 bpm @ 755 psi, Observed nut plug at shakers after pumping 310 bbls lead, Switched to Tail & pumped 49.6 bbls (230 sxs) plus additives at 15.8 ppg at rate of 6.1 bpm @ 880, Shut down & drop top plug, Displace plugs w/ 20 bbls fresh water, Switch to rig pumps & displace w/ total of 181.0 bbls 10.0 ppg mud at rate of 8.0 bpm @ 570 to 800 psi, Slowed rate down to 3.1 bpm @ 550 to 610 psi on last 6 bbls, Bumped plug w/ 1100 psi, C.I.P @ 12:53 hrs 3/08/06, Floats held. Had full returns thru out job w/ 106 bbls 10.7 ppg cmt returns to surface. Stopped reciprocating casing after pumping 25 bbls of mud displacement due to decrease in down weight. 13:00 14:00 1.00 SURFAC CEMENT PULD P 2,731.0 2,731.0 Blow down lines - RD cmt lines & head - LD landing jt. 14:00 15:30 1.50 SURFAC DRILL RURD P 2,731.0 2,731.0 ND surface riser 15:30 16:30 1.00 SURFAC DRILL OTHR P 2,731.0 2,731.0 Install FMC wellhead & test seals to 1000 psi 16:30 18:00 1.50 SURFAC WELCTL NUND P 2,731.0 2,731.0 NU BOPE Latest BOP Test Data - - -- --- - o~ie -- - --- i ~~~ P~,~ 3/8/2006 250 & 5000 si H dril 250 & 3500 Page 1/2 Report Printed: 12/28/2006 Security Level: Development Time Lo tig: DOYON 19 Daily Drilling Report CD3-111 Report Number: 5 Report Date: 3/8/2006 :%r;,..~ End Tice: Time Dur {h+'s) Phase Op Code ', T~~c-~e ~~ - _ ~'F'-~J-~ ~'i y - ~. -- - _... f~~pth Start Irbl Core ~ 1._i Gass- :ftKB) Depth Cn; (ftKt=,j ~ ~ ,~~~;-- ,hc~r. _ 18:00 23:30 5.50 SURFAC WELCTL BOPE P 2,731.0 2,731.0 RU & test BOPE - Hydril to 250 & 3500 psi -pipe rams, blind rams ,choke i~ kill line valves, choke manifold , TD IBOP's, dart & floor safety valve to 250 & 5000 pis - Prformed accumulator closure test. witnessing of test waived by John Spualding AOGCC 23:30 00:00 0.50 SURFAC WELCTL BOPE P 2,731.0 2,731.0 Pull test plug -set wear bushing -blow down lines -- - ',Mud Check Data 1 ,;,_; Dr-,pm !ftK8) Dem b -> >.; v s ~ ~%qt) i'v I-. r.p ----- _- - YP Caic Ged ('I Os) ~I ':icYi >el (30m) HTHP Filt Den. `v I erne li ~ orr. ) (Ibfl100H') (Ibfl100ft~) t 1 1 JOtt'; ~ 16f/100ft') M8I L,c~l ~ (mL130min;~ ul I ~spud mud 2,731.0 9.90 73 ~ 14 _ __ --- .0 16.000 7.000 30.000 33.000 25.0 9.0 9.0 ',Injection Fluid Fluid Source From Leasefbbl) DesGnahon Noce Diesel CD3-111 15A CD3-109 Other CD3-111 530.0 CD3-109 Recycled mud CD3-111 1233.0 CD3-109 Water CD3-111 90.0 CD3-109 --- _ - Wellbores Wellbore Name Wellbore APIIUWI CD3-111 501032052600 - -bon a~ rni t; i Act Top (frKBJ =AcPBtm (ftK8)Start Date +`E~ Dafe COND1 - - -- -- - 24 --- ---- 0.0 114.0 2/15/2006 2/15/2006 SURFAC 12 1/4 114.0 2,731.0 3/6/2006 3/7/2006 INTRM1 8 3/4 2,731.0 8,670.0 3/9/2006 3/11/2006 PROD1 6 1/8 8,670.0 15,073.0 3/14/2006 3/19/2006 Cement Surface Casing Cement -Started 3/8/2006 Type Wellbore String Cement Evaluation Results casing CD3-111 9 5/8" Surface Casing, 2,721.OftKB Pressure tested to 2500 psi for 30 mins. Stg No. Description Top (ftKB) Bottom (ftK8) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.0 2,721.0 3 610.0 Fiu~d Class _ v 1-hr~ ~ Density (lbJga~) Yield (f w Cs Top (ftKB) EsfBtm (ftKB) Amounr Ise Lead Cement G _ 410 325.4 10.70 4.45 36.0 2,221.0 Tail Cement G 49.6 15.80 1.17 2,221.0 2,721.0 Page 2/2 Report Printed: 12/28!2006 Well Name: CD3-111 Rig: Drilling Supervisor: D. Burley / D. Mickey Type Of Test: Casing Shoe Test LOT/FIT Hole Size: 8-3/4" ~ Casin Shoe Dept RKB-CHF: 34.0 Ft 2,721 Ft-MD 2,46.9 Casing Size and Description: 9-s/s" 40#/Ft L-80 BT Casin Test Mud Weight: 9.9 ppg PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 3/9/2006 Volume Input Volume/Stroke Pump used: #z Mud Pump ~ Strokes ~ 0.1000 Bbls/Strk ~ ~ Pumping down annulus and DP. ~ Casin Test P h Hole Depth Pumpin Shut-in Pt Ft-TVD 2,751 Ft-MD 2,494 Ft-TVD Strks psi Min psi Strk; ~ ~ 0 0 0 2530 Mud 10 min Gel: 22.0 Lb/100 Ft2 Mud 10 min Gel: Test Pressure: 2,500 psi Rotating Weight: Rotating Weight: 130,000 Lbs Blocks/Top Drive Weight: Blocks/Top Drive Weight: 74,000 Lbs Desired PIT EMW: _ Estimates for Test: 1.7 bbls ~ Estimates for Test: _I EMW =Leak-off Pressure + Mud Weight = 990 + g 65 ppg 4 Lbl100 Ft2 6 Lbs 8 Lbs 10 ppg 12 1 psi 0.7 bbls 14 1 ~ ~ 16 1 15 Second 18 1 0.052 x TVD 0.052 x 2469 Shut-in Pressu EMW at 2721 Ft-MD (2469 Ft-ND) = 17.4 ppg 550 3000 2soo Zooo w o: N 1500 W a looo soo _~ _ --- - Lost 60 psi dunng test, held 97.6% of test pressure. ~ ~ ~ 1.- 0 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST tLEAK-OFF TEST O PIT Point 4 251 5 25C 6 25C 7 24~ 8 24~ 9 24E 10 24E 15 247 20 247 ume Pump Rate: 0.8 Bbl/min ~ In te rit Test Shut-in i Min psi 0 0 670 80 0.25 550 50 0.5 550 60 1 540 80 1.5 53 7 `- 640 3 525 8 ~~` 680 3.5 525 9 `" 720 4 520 10 ' ' 770 4.5 520 11 " ~~ 820 5 520 12 y 870 5.5 515 13 ` ' 910 6 510 14 960 6.5 510 15 990 7 510 ~1 ConocoPhilli S Casing Detail 7" Casing Well: CD3-111 Date: 3/13/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.20 FMC Gen V Hanger 1.68 34.20 Jts 3 to 202 200 Jts 7" 26# L-80 BTCM Csg 8535.35 35.88 Weatherford Float Collar 1.24 8571.23 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.36 8572.47 Ray Oil Tools "Silver Bullet" Float Shoe 2.08 8657.83 8659.91 TD 8 3/4" Hole 8669.91 8-3/4" Hole TD @ 8670 ' MD / 6933 ' TVD 7" Shoe @ 8660 ' MD / 6932' TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 138,139,140 Straight blade centralizer one per jt on every other joint Starting @ # 142 to 200 Top Nechelik - 8570' MD 6925 ' TVD 225 joints in shed - 202 total jts. to run Last 23 jts. out Use Run & Seal i e do e Remarks: Up Wt - 275 k Dn Wt - 170k Block Wt - 75k Supervisor: D. Burley / D. Mickey ~s .^- ~ Cement Detail Report CD3-111 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10103852 3/4/2006 3/6/2006 3/25/2006 !Cement Details Description ~ - ,Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/13/2006 00:00 3/13/2006 15:45 CD3-111 Comment !`Cement Stages - __ - - - - IStage # 1 _ __ _ _ _ _ _ __ _ Description Objective Top (ftK6~ Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Primary Cementing 7,729.0 8,660.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 4 520.0 Yes No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives _ --_ -_ __ Fluid.. Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) CW 100 6,396.0 6,929.0 20.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label --._ Fluid - -- - - - --- Fluid Type Fluid Description - Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush 6,929.0 7,729.0 30.0 Yield (ft /sack) Mix H2O Ratio (gat/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Flwd Description Estimated Top (ftKB) 7,729.0 Est Btm (ftKB) 8,660.0 Amount (sacks) 190 Class G Volume Pumped (bbl) 39.2 Yield (ft /sack) 1.16 Mix H2O Ratio (gat/sa... 5.09 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/16 Report Printed: 12/28/2006 ~' ~1 --~--~.. Security Level: Development Daily Drilling Report CD3-111 Report Number: 10 ,. . Rig: DOYON 19 Report Date: 3/13/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) CD3-111 Development FIORD NECHELIK 3/6/2006 7.77 8,670.0 8,670.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10103852 3,960.04 190,997.35 366,085.04 2,160,959.48 5,411,831.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) 7" Intermediate Casing, 8,660.OftK6 Ops and Depth @ Morning Report 24hr Forecast RIH w/ BHA #3 - PU 4" DP f/ pipe shed Finish RIH -Test csg - C/O shoe Track -FIT -Drill 6 1/8" hole Last 24hr Summary Finsih running 7" csg -Circ - Cmt 7" csg -Set & test pack -off - MU BHA # 3 General Remarks Weather Head Gount -20 / - 50 WC / NE@16 mph 46.0 - - _ __-- -- 'l,upervisor _~ - _._..--- Title Dave Burley Rig Supervisor Don Mickey Rig Supervisor Time Lo -- _ ___ _ Start End Dur ''. ~Tr,~e - - - - - Depth Stt ii Dapii-~. End Time Time (hrs) phase Op Got- npg.; ;~ IP-R-T Trbl Code Trbl Gass_ (ftKH) ~h.H) rn rt`peratior~ 00:00 01:00 1.00 INTRM1 CASING RNCS P 2,699.0 Run 7", 2G#, L-80 BTCM casing from 1,285' to 2,699' (63 jts total) 01:00 01:30 0.50 INTRMI CASING CIRC P 2,699.0 2,699.0 Circ and condition mud - 5 bpm / 320 PSI PUW 150K SOW 120K 01:30 03:45 2.25 INTRMI CASING RNCS P 2,699.0 5,295.0 Run 7" casing from 2,699' to 5,295' - (124 jts total) 03:45 04:30 0.75 INTRMI CASING CIRC P 5,295.0 5,295.0 Staged pumps up to 5 bpm ICP 730 psi -FCP 450 psi PUW 185K SOW 155K 04:30 07:15 2.75 INTRMI CASING RNCS P 5,295.0 7,740.0 Run casing from 5,295' to 7,740', unable to work past tight spot at 7,740' 07:15 08:00 0.75 INTRM1 CASING OTHR T Hole Underga... 7,740.0 7,683.0 Picked up to 7,725', attempted to circ -pipe packed off. Conditions Ho. Lay down one joint of casing and pull up to 7683'. 08:00 09:00 1.00 INTRM1 CASING CIRC P 7,683.0 7,683.0 Establish circulation -staged pumps up to 4.7 bpm / 440 psi -circ and condition mud 09:00 10:15 1.25 INTRM1 CASING CIRC T Hole Underga... 7,683.0 7,769.0 Wash down two joints from 7,683' to 7,769' - 4.5 bpm / Conditions Ho. 450 psi -worked through tight spot from 7,702' to 7,710' - cleaned up after several passes. 10:15 11:45 1.50 INTRMI CASING RNCS P 7,769.0 8,660.0 Continue running 7" 26# L-80 BTCM csg f/ 7,769' to 8,624' (202 jts total ran) PU FMC fluted hanger & landing jt. -land casing in wellhead w/ shoe @ 8,660' & FC @ 8,571' - String wt. Up 275 K Down 170 K 11:45 12:15 0.50 INTRM1 CASING RURD P 8,660.0 8,660.0 LD fill up tool -Blow down TD - RU cement head & lines 12:15 14:15 2.00 INTRM1 CEMENT CIRC P 8,660.0 8,660.0 Establish circulation @ 2.0 bbls/min @ 440 psi -Stage pumps up to 5 bbls/min @ 520 psi -Circulate 8~ condition for cement job -FCP - 450 psi @ 5 bbls/min Had full returns while circulating PJSM w/ Dowell and crew 14:15 15:45 1.50 INTRM1 CEMENT DISP P 8,660.0 8,660.0 Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to 4000 psi -pump 15 bbls CW-100 @ 4.1 BPM @ 450 psi -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4.4 BPM @ 525 psi -Drop btm plug -Mix & pump 39.2 bbls (190 sxs) Tail slurry (Class G w/ .2% D046, .3% D065, .07% 8155, .4% D167) @ 15.8 ppg - 4.5 BPM @ 700 psi - Drop top plug -Pumped 20 bbls water w/ Dowell - Switch to rig pumps & displaced w/ 311 bbls 9.8 ppg mud @ 6 - 7 BPM @ 190 to 540 psi -slowed rate to 3.5 BPM for last 10.0 bbls - 540 psi final -did not bump plug - check floats - OK - CIP @ 15:45 hrs. Full returns throughout job, Worked casing 20' until last 23 bbls of displacement Latest BOP Test Data __ Date r ,„,x 3/8/2006 250 & 5000 si H dril 250 & 3500 Page 1/3 Report Printed: 12/28/2006 ~' ~~ Security Level: Development Daily Drilling Report CD3-111 Report Number: 10 Rig : DOYON 19 Report Date: 3/13/2006 Time Lo - Stara End - Dur ''.. Tui = _ _ _ Depth Start Depth G~.: Time Time ihrs) Phase Gy Cc .:pSu ~ Lo_. ~-N-i l r.>I Code ~~ TTJ, Gass. (ftK$) (ftKF.'i ~ ,.'Up - tio;; __ -__ 15:45 16:45 1.00 INTRM1 CEMENT RURD P 8,660.0 8,660.0 RD ctm lines & head - LD landing jt. - LD csg elevators & slips 16:45 17:30 0.75 INTRM1 DRILL OTHR P 0.0 0.0 Pull thin wall wear bushing -Set & test 7" pack-off to 5000 psi 17:30 19:45 2.25 INTRMI WELCTL EORP P 0.0 0.0 Set test plug -change top pipe rams to 3 1/2" x 6" VBR - Test to 5000 psi -Function lower pipe rams & Hydril - Pull test plug 19:45 20:15 0.50 INTRMI DRILL OTHR P 0.0 0.0 Set wear bushing 20:15 21:00 0.75 INTRMI DRILL PULD P 0.0 0.0 PU drilling bails & DP elevators 21:00 00:00 3.00 INTRMI DRILL PULD P 0.0 116.0 MU BHA #3 -bit, GeoPilot, MWD componets - Up load MWD Mud Check Data YP Calc Depth (tth h =Deru (Iblgal~ Vis tslgt) PV Calc (cp; 't`1'^"~"'~ GPI '. 's, .~P ro-,~. - '. ~- ~ H~HP Filt DensltyTem ~Ib!' ~U'Pj (rb6rlwti=j Itt 'r'~r~;.l MHi {Inroh ; (mLJ3Umin) pH ~ {°F) p Solid: Corr (-~~; Water 8,670.G 9.80 37 9.0 17.000 8.000 12.000 13.000 15.0 7.1 9.1 9.5 Based Mud Injection Fluid - - - - _ - - . Fluid Source Destinatio~~ Note From Lease (bb~`. Water Based Mud CD3-111 _ 1030.0 CD1-19 __ l Run No. 3 - 6 1/b Drill Strin s: B HA No. 3 - 6 1/8" BHA #3 / Bit in, Securi DBS, FSF 2553, 10751523 _ _ _ _ _ _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") _ ___ IADC Bit Dull String Wt (10001bt) WOB (max) (100... WOB (min) (1000... 8,670.0 10,657.0 0.45 14/14/14 0-0-NO-A-X-O-NO-DTF 9 12 0 Drill Strin Components - - - -- -- Jts Item Descnpti.:~ OD Qn) _ ID (in) Top Conn Sz.(ir'~ ~ Tr T r?ad Cum Len fftl _ 1 Geo Pllot 4 3/4 1.500 3 1/2~NG 38 17.38 1 Drill Collar -Flex Non Mag 4 3/4 1.500 3 1/2 NC 38 28.92 1 Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 32.51 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 41.06 1 MWD GR/RES 4.73 1.500 3 1/2 NC 38 64.87 1 MWD DENSITY 4.74 1.500 3 1/2 NC 38 90.29 1 MWD (Dar & Logging) 4.7 1.500 3 1/2 NC 38 101.11 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 111.13 1 Float Sub 4.66 2.313 3 1/2 NC 38 113.54 1 Stabilizer (Non Mag) 4 3/4 2.250 3 1/2 NC 38 119.02 1 NMDC 4.64 2.250 3 1/2 NC 38 150.02 1 NMDC 4.52 2.250 3 1/2 NC 38 180.95 1 NMDC 4.54 2.250 3 1/2 NC 38 212.03 1 XO Sub 4 3/4 2.563 4 XT 39 214.68 3 HWDP 4 2.563 4 XT 39 306.68 1 Drilling Jars -Mechanical 4 3/4 2.000 4 XT 39 339.14 2 HWDP 4 2.563 4 XT 39 400.50 Drillin Parameters „(, ~i RPPA PURL F.~tHI mmlft _ ~ _ ~7 i HC ~-- -- Sliding ors Cum Dep~Y iftj I ii ~ ~ Dnll t i~i~ ~ :'JOB (Ib~ (rPml i 3PP ~, I~s~l... (10001bf) ( ° . ;:k i ~I )'i hslrri 1 ~~ En Sta -.... D~ Tq _. --` -- --- 8~67G.G 8,67Q G ---~ ----- -- i ~ - I ~ Wellbores Wellbore Name Wellbore API/UWI CD3-111 ~ 501032052600 lion ~ i. e ~rri Nc~ l "~ (ffKB) Act Btm (ftKB ~ Start Date End "' - - - ~ 1 Dafe _- __ -_ _- _- - - 24 - C©ND1 - 0.0 114.0 2/15/2006 2/15/2006 SURFAC 12 1/4 114.0 2,731.0 3/6/2006 3/7/2006 INTRMI 8 3/4 2,731.0 8,670.0 3/9/2006 3/11/2006 PROD1 6 1/8 8,670.0 15,073.0 3/14/2006 3/19/2006 _- - -_ _ Cement - - -- _- I Intermediate Casin Cement -Started 3/13/2006 Type Wellbore String Cement Evaluation Results casing CD3-111 7" Intermediate Casing, 8,660.OftKB Page 2/3 Report Printed: 12/28/2006 ~1 .+. . Rig: DOYON 19 Daily Drilling Report CD3-111 Security Level: Development Report Number: 10 Report Date: 3/13/2006 Stg No. 1 Description Intermediate Ca sing Cement Top (ftK6) 7,729.0 Bottom (ftK6) 8,660.0 Q (end) (bbl/... 4 P (final) (psi) 520.0 __ Ruid Class Amount (sacks) V (6bO Density (Ib/gal) Yie3d.(8'Isack) Est T op (ftK6) Est Btm "`.K8! CW 100 MudPush Tail Cement G 190 20.0 30.0 39.2 8.40 12.50 15.80 1.16 6,396.0 6,929.0 7,729.0 6,929.0 7,729.0 8,660.0 Page 3/3 Report Printed: 12/28/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-111 Rig: Doyon 19 Date: 3/14/2006 Volume Inpu Drilling Supervisor: _ Mickey /Burley Pump used: Cement Unit ~ Barrels ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Cas Hole Size: s-3/4" ~ Casin Shoe Depth Hole De th Pumpin RKB-CHF: 36.1 Ft 2721.0 Ft-MD 2469.0 Ft-TVD 7729.0 Ft-MD 6552.0 Ft-TVD Bbls psi Casing Size and Description: 9-s/s" 40#/Ft L-80 BTC ~ Chan es for Annular Ade uac Test Pressure Inte rit Test Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg Casing description references outer casing string. Inner casing OD: 7.0 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg Estimates for Test: 668 psi 0.5 bbls -- _ _L ~i EMW =Leak-off Pressure + Mud Weight = 615 + 9 8 PIT 15 Second 0.052 x TVD 0.052 x 2469 Shut-in Pressure, psi EMW at 2721 Ft-MD (2469 Ft-TVD) = 14.6 424 looo w o: N 500 W a Bbls/Strk ~ ast Pre: Shut-in Pum lin psi Bbls 0 0 1 0.5 2 1 3 1.5 4 2 mp Rate: Bbl/min ~ e rit Test Shut-in Min psi 0.00 450 1.501 41 8 4 567 3.50 401 9 4.5 516 4.00 401 10 5 494 4.50 398 15 5.5 511 5.00 397 20 6 489 5.50 395 `. ~ rra Summary oa ~ ~ i• ~ ~ i ~ ~ ~ i ~ ~ a i 0 1 2 3 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes 'CASING TEST f LEAK-OFF TEST O PIT Point SURFACE CASING SHOE SEPARATION FROM CD3-111 CD3-111 x Y Surface Casino Shoe ASP 4 Coordinates NAD 27: 387821.0 6004710.6 ells Details @ AOGCC Ann. Disp. Permit # ermit Date ource well Ann. Vol. ** tart Date nd Date is ante from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments CD3-108 1 3 .3 6004986.4 17.1 2431 16.9 not for annular dis sal CD3-109 306-020 1/2012006 CD3-110, CD3-111, CD3-112, CD3-307, CD3-302 60160 1/20/2006 4/27/2006 1099 388917.3 6004780.2 18.0 2414 16.0 CD3-110 743 388563.7 6004720.7 16.7 2439 15.8 CD3-111 0 387821.0 6004710.6 17.4 2469 14.6 CD3-112 307-002 1/11/2007 CD3-113, CD3-107/CD3-307 21173 1/22J2007 2/12/2007 528 387406.8 8004382.6 18.0 2485 15.1 CD3-307 n 1866 389627.9 600445 8 18.2 2479 15.4 Also known as CD3-107, first annlus, before cut and pull operations Feb 2007 CD3-302 n 1023 388815.4 6004469.9 18.0 2505 ne on surface casi Set CD3-113 n 839 387570.6 6003910.0 18.0 2475 16.3 ' Lateral distance in feet, between surface casing shoes, in the X-Y plane " As of February 12 2007 Note that this sheet is not the definitive record for annular disposal volumes `~ WELLPATH DETAILS Ph i I I i C onoco ps CD3-I 11 Alaska 5olo3zo526o0 Ref Dat~wn CDD3 III. 44JOR Quarter Mile V.Sec[ion Origin Origin Startng (1320 feet) le +N/-S +E/-W From TVD NALLIOURTON An g >M~r a~ srwe.. 330.16° 0.00 0.00 36.10 ra lus p of 2724 2043 ~- 1362 0 0 681 0 -681 3405 2724 2043 1362 681 0 681 1362 2043 2724 West(-)/East(+) [ft] -_ CD3-112 CD3-11 2 CD3-111 CD3-111L1 CD3-109 CD3-109 CD3-111 CD3-302 CD3-302PB2 CD3-110 CD3-110 i ~ _ CD3-302 CD3-302PB1 CD3-108 CD3-108 CD3-307 CD3-307 ~ C D3-307 Plan: CD3-107 /~ - - - --- / ~.~~ az~ci sYi~arlrc~r , 'r'~tz h~tr~ ?-eYt~uest~d to dispose of "ne,~r-px°r~~lu~t" ~'~.erar, i.p fluids from tYx~ r€~ut i ne m~hirzc. of mzzd and c~.^~;~zzv at h"1~->ar.~ as Thr.ll ast tY<e vlea's ulz iai.~s rr~z.r?tinct f ~ ~rti c_~~az~ing out floe t~:s~s at t}ze rnuci ~larrt sr ~r~1~;~ratr~ra for t<sing tail base ;r~.ud, Tr ~r,:tni~-:siv:i~ t~~c prep~.~~t1i:sY.^,~ aak~Y-~ati>rd dz^gosY~q z~f t2>~ 'ss~~.~ ~.~xc~~uct" ~.l~~i~ ~zla ~,.*i~ ~r~~ular disp~;~al at ~U 1 .pad. Tiu~~ to the ~ealvyi~a~. settir:<;; ~t ~_lYaizle, ~'l~ss 1 and C'~ass 2 di~:posal t7~7tic?t2ra ~r~ l_ir,itecl. k'':z~l~i~s' px-~~do~~~sor, Fs:2t'C}, had e~t~:k~`~.i~>ze~ ~.he lmit.at~rz of cz>pea.~n1. c~ptic~r_~ tv life ~`or~~tt:iss~.c~z:`:~ satzs'~~`ric~z; ,~rd a7r_~Jlar di5v~~.~1 ura• :~p~r~vscs as tt~s ;as ctc<~ ar~d envirorzm~ntal altez7rati~.{e. Ir these requs/sts the ~Aa`Mt~ flui.€is ~r'ze nC~ c13 ~f~~z-c~rt ti-~aa rxr.eviously appzt~v~<k, atsei a r. 4= -ham rr•~tz1t o the ont~roirscj developnierxt attva.t:.e.s 3t r11}~~nc_ The t_ort,rtz.~ssc>ners Yt~,v~ 3z.~thorY~ed m~ Lta ~en~3 you tYr_s m~~ssac~e. By c©~iy of !: to . er?:ail, Phiili,as is aut2~cri~er~ tCs rzsp~?se cif ~: lean up fluids as de~~cribeci in yraur ~Tai1. Please ~~al l w:i r Y; ~'~ny z~ues t a ors . `P~m ~assnc~c-x , P G 5r. r^µtrealeuszs Bnr~is~.~~z' '~.3,P c.rsv {'c~:xrt~ b:T'nt,~: .7` JGt'~Y 2~is • l1tL~i,.~ir~G~, ~ iii nctec i.z tt,e atC~1C`:z~;d email, `I crtn [wiazis~irz Iax`=~vi.o'asl~r r~e~ze~ted :: z:u"~ic,ri ~at_ion to di ~}~a e of *sevr-grcadsct c~lea<s =ap f1ui~Y5 s~.ach as rem~z.t r rinsate, a:zt3 m~uci dzac~ iris>e pit z'i:~s?S Fr~~zzz ?s~txing o;7c~ration~ ~Tia anrsular .- inec:tivn ir. ~az~x-mitCC~c~ t~.~el1.s Ur the -~1~inc~ Cl7l >~ri11 mite. 1~~ r`iot.~d 2~e1~?:~t, °- r.t7GC~' r~~apro~~~d such dish{~s.al at tt<e C?~1 I?rill ~~1~ in 199, b<~s~r' oz3 do integral relatifns`.iip~ G£ the tztzzzl Ti.~ x~.r'iC~ [are l`y and t2ze .can-site c~ri11ir3t~ ~• Qperar..ic~r~ _ r :- Phillip: ~~~tzld 1. _ykz~ t::~ c7ntinu,n~ pursz.iz:cr t?zi ~ regtaest. :~ign.ficciXSi, e~7.eexr: tour cry tank: ?T. thz', mszd mixing faeiwity mint u~c:rr :in prera~~r4~ztion [ear tho > tcrnpearary u~~;G of oil }~aueci stzuc3 ~rr3auct~; at r"~1F7iri~ z.n thy: c:omir.~ months. > ^ts~ avai~.abilit~.~ of ~znnul.a~ dis~OS~z~ ati ~rz ~a~a.on for tank rinse fluici~: and ~ cit~il~~r U;ast~.s wcxt::it9 grc~3r.ly fae^a.lita-c~ t:~is prnc~~s. (='YI'ro~ally, rout .r<e :- rinses ar€~ ber_eficially reused, Y:~rawe~.~~r. tY.er~ ~_:~ a cdr,~~rs: akac?zrt the 1 p4tentia= ct:anL-ity f~f il~i.d tt,at ce~uhd ~e g~sx~x~~ted duz-ing tl-fis larr~e scale ~- a=1e~n ula prr~~~ss_ ) r r"ar,ks ~~;. the -zd sriacirrg facility nksy c:ari~_a.rs ~S thex ~z~~,a az:ci usetYl mud ~ product.. is~,~~act`rs ri:~ses in CC~:s~aCt '.~~i~h tzNed pz~QC.iucts may be '~.zajectet3 is } t7ie permitted class .i'1. c3a~.s~r~sal. Orel ~ GCI~] q~} , rinse y of ne*,; prr~eluct~ wc~u1~3 ~> ;~«~~ntial.ly he. rot~t~d to the class z ~lisi?:asa- E.;~>il ~y~'i-f}2} , uf7ere tt.~re i~ > a tiiffi~t~l~y mara~izag .~olir~,~ stirsent. The cuss l w~li is ~ ~riti~al 1af41ino for Lacility infrast*_°u~;turer being the dxslar~sal 1~?r..~r.~zan foY all c3c~zztcx:tic effluent, and i~,: iU a ~rioz:~ty t:o ~xQ~,renr ~~nv com~arumi~c~ to tna.s } dispa«1 f<a~ility. annular c~ispc~s.-xa. ~resey?ts a prcrferrod s,Yast~ masagemerst > alt~rnat.ir~ ir. t1i.~ ~~is~. ~r .~ 't'i?anc you ~e_y tc~u~h fox yc~u~' ca_rsi~e~ati~zi Crf trzs rr~gtlc~~%. F1~a~L dc~ not ~ he:~itate , ~, ~:~nr~~"_. ~e ~~` zr aiC~~~na~~ ~~~_~~ ~ttu~i3 or ptrc~~ at t~~0~} ~; ~-~~~Jf~ > if }eau h~.~°,f~ ~;~,}4?sstlot?~ oi: neec'c ~c3~~5`ze~na' in~c~rrrvatir~n. '' Sh7nron ~on*te33,.r } a'~pir~e ^i~=c Eri~.ri_<3z~~iental W'losai riat;G~~' ---__ ~'oY;aarde~i ~~ T~LP ~t7~~ ~~or~fPPt.fi~ ~z I1~O~,~~a~. 32;x£7 C>f. ._~~.~~ s 1,I.,P Ert~, t:~~tzs z~ t7~j31JQ? 12:f~.`? PN. fi > <U: ~0;"; 1t~i;AI:C~EtJC1,~dt~7111n.>tdZ'~.~3_C.tl ,. Cc. t u. > ~ul~j~ct.: fl~Qk>/SL. tt~ :4:z?~ec~ C~m~nt ctiz':~~~-c ~t cn ~ I~e~r 2-fr . Nkztarr<ie~` , t In~~~ts.~;r? ~;f c~mx~r~t t';~l~r~r~ ~z:t: r:.l.r~~n-u~ fluid: f_-c:;z~ ;z?uri an~3 kati irre mixing c~~~ratiorr~ at t:~~ Xlpine mud gl=nt faLilsCy :into ~?~~,rc~~-ed ~nnulaY ~~sDe~~~1 t e~~a~~`ati~;r?s t;c?s tfix~'~n~;~d key ';~c~ nlz?Si:<Z t7 i. j. :u7;1 GaN lonse~--~~ativri CraztuniSSi~;rr } f~C~GCC} 3:-t the 1'farch ~'7, J~~~~ letter prom ~'~t?VC£' t~ `,tiu4 t:1~osYc~x' c>f Al~t;t~ > r~laSka, I.ic. , r;~+r,~ E~hilligs Alaska, Tno. {E~~~) Tho apprr~val vas granted tc~` > FAZ sfa~c, f i cai ly fox ~::1.f-37 nc~ I)xi t l Sites CD1 and aatro~ i z~C< vs~_lux;;e~. up t.o } 35, t7fl~J L+~rrels thrr~u~h thz arrr_,alar sr~~t~~. 3 F~~,' request that ~rri~ apgroual by exterrdecl ti~s dr~'ll.an~ cx~;~._~ti:rz?> ar, fl~-iir~'- -~ Dr:~ll Sites Cll. i~etti~rt i~ixin~ r.>f:~r~C~ors ~c;r r~tr.it~ >urface er~ncluetc~rs .- +M i ~ l lae t.~k-t~ pl~L~:_ at the grind and Inject fac.ilit~~ ztif~ticil is <.tt~r~rt~ l1 > a~tacl?ee t~ G°h~ clryllinc~ ri~~ ~t ~'D2. t;pun ~carn~l~;~?..,~r of the c~uncrn`in~7 in cif the ~~il~tts~tor~, r};~ l~tE'~ a:tc: taxng tank +,.i11 aa~:~e t« }~Y xxtyec< and tare ?~ h'7.t;~ci~e d?Spc~s~d 4~. P%MI riG:~;.te~z` crjlj.7rl~ir~t.1. 'C f7 L:l~P..:~.li- a-,jl;l.~ T.':l..r'..c3tt?, c`.fnt"j. atir~r ~l~t;:~-u~ :~t;~t C}•e r~ac. ~~s:c3 t>r. ixl~: mixing or~eratza~ts. .:rtu t_he annual Glace ~f n~prr~v~d ~.~ells lrcat~d at Dr_ll Ct~ CL?2. > I> goat ?~~s.-~._ any qucstic;:?s ~lcasc~ ccntact m~ Gt ~7~?-~2[lzJ, ~- Al~ir~~ Field Envircruttental Ca?lianc ~tr~-s~rnaundar.vcf a ~ ~ O ~'°" ~ `~ ConocoPhilli S Casing Detail Well: CD3-302 9 5/8" Surface Casing Date: 2/3/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.87 FMC Gen V Hanger 2.17 36.87 Jts 3 to 69 67 Jts 9-5/8" 40# L-80 BTC Csg 2559.35 39.04 Weatherford Float Collar 1.41 2598.39 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.35 2599.80 Ray Oil Tools "Silver Bullet" Float Shoe 1.40 2677.15 2678.55 TD 12 1/4" Surface Hole 2688.55 TOTAL BOWSPRING CENTRALIZERS -37 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 3 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64,66 74 jts in the pipe shed. 69 jts to run -last 5 jts stay out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torgue - 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt - 130k Block Wt - 75k Supervisor: Lutrick/Mickey r~ ~ Cement Detail Report CD3-302 Surface Casing Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date ROT -DRILLING Drilling 10099503 2/1/2006 2/1/2006 2/15/2006 - - -- - -- Cement Details' Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing 2/4/2006 14:53 2/4/2006 16:16 CD3-302PB1 Comment Cemented 9 5/8" casing as follows: Pumped 40 bbls fresh water w/ Biozan as pre flush w/ nut plug as marker w/ rig pumps -Switch over to Dowell -Pumped 2 bbls water -Tested lines to 2900 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 4.4 BPM @ 256 psi -Mixed & pumped 293 bbls 10.7 ppg Lead slurry (ASL) @ 6.3 BPM @ 265 psi Observed nut plug marker @ shakers w/ 270 bbls lead slurry pumped -pumped down surge can) Switched to tail slurry -Mixed & pumped 47 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 6.0 BPM @ 175 psi Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cement w/ 179.5 bbls 9.9 ppg mud @ 7.5 BPM @ 300 to 837 psi slowed pump to 4.0 BPM (for the last 7 bbls of displacement) Bumped plug w/ 1200 psi -Check floats OK - CIP @ 1616 hrs. -Full circulation throughout job w/ 100 bbls 10.7 ppg cement returns to surface -reciprocated pipe during circulating & into cement job to 50 bbls of displacement -hole getting sticky - landed casing for remainder of job Cement Sta es Stage # 1 - _ _ _- - -- Description Objective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Cement Casing 0.0 2,679.0 100.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 610.0 1,150.0 15.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Pipe movement: Reciprocating Drag down (Ibs): 150000 Drag up (Ibs): 170000 Time started reciprocating: 12:45 Time stopped reciprocating: 15:45 Cement Found Between Shoe and Collar (Y/N): N Cement found on liner tool (Y/N): N Annular flow after cement job (Y/N): N Pressure before cementing (psi): 340 Hours circulated between stages: 1.3 Bbls cmt to surf: 100 Method used to measure density: Densometer Method used for mixing cement in this stage: Tub Returns (pct): 100 Time cementing mixing started: 14:53 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) FLUSH Biozan water w/ nut 0 40.0 plug Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 8.30 0.00 0.0 Additives Additive Type Concentration Conc Unit label - _ - -- __ - Fluid __ _ - _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Spacer MUDPUSH XL 0 50.0 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 10.50 0.00 0.0 Additives Additive Type Concentration Conc Unit label ~~Fluid -- -- ii - - -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) LEAD ASLite 0.0 2,179.0 397 412.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.72 0.00 10.70 0.00 0.0 Page 1/2 Report Printed: 12/28/2006 ~ Cement Detail Report CD3-302 Surface Casing Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date TEST TESTING 3/31/2006 Additives Additive Type Concentration Conc Unit label ICement Fluids & Additives _-- - _ -- -- - - __ ___ Fluid --- __ _ _ - Fluid Type Fluid Description Estimatetl Top (ftKB) Est Btrn (ftKB) Amount (sacks) Class Volume Pumped (bbl) TAIL 2,179.0 2,679.0 235 G 49.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 0.00 15.80 0.00 0.0 Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 12/28/2006 Security Level: Development Daily Drilling Report CD3-302 Report Number: 4 >. Rig: DOYON Doyon Report Date: 2/4/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) CD3-302PB1 FIORD KUPARUK 2/1/2006 4.00 2,689.0 2,689.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10099503 443,982.00 922,307.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,679.OftKB Ops and Depth ~ Morning Report 24hr Forecast PU BHA # 2 MU BHA - RIH - CO ST -FIT -Drill 8 3/4" hole Last 24hr Summary Finish POOH - LD BHA -Run & cmt 9 5/8" csg - ND surface riser - NU BOPE General Remarks Weather Head Count Supervisor ~ Title Donnie Lutrick /Don Mickey Supervisor Vern Johnson /Liz Galiunas Engineer Time Log Sta~ Ertd Dur Time Depth Start Depth End Tim? ~~ Time (hrs) phase Go ruck DpSub-Co... P-N- ~ ~ r- Code Trbl Class. (ftK6) {ftKE11 (~ ~mr~6F*aration 00:00 00:15 0.25 SURFAC DRILL TRIP P 1,173.0 892.0 POH w/ 5" DP from 1173' to 892'. Check flow. OK. 00:15 01:30 1.25 SURFAC DRILL TRIP P 892.0 76.0 POH and std back HWDP. 01:30 03:30 2.00 SURFAC DRILL PULD P 76.0 0.0 LD MWD, motor and bit. 03:30 04:00 0.50 SURFAC DRILL OTHR P 0.0 0.0 Clear floor. Remove bell nipple ring. 04:00 06:00 2.00 SURFAC CASE RURD P 0.0 0.0 RU 9 5/8" csg equipment. 06:00 06:15 0.25 SURFAC CASE SFTY P 0.0 0.0 PJSM with all personnel on running csg. 06:15 09:30 3.25 SURFAC CASE RUNC P 0.0 1,335.0 Ran 9 5/8" 40# L-80 BTC csg as follows: FS (Ray Oil tools silver bullet) 2 jts. FC (Weatherford) 2 jts.(first 4 connections made up w/BakerLoc -filled pipe & checked floats) 31 jts. to 1335.26' (35jts. total) 09:30 10:15 0.75 SURFAC CASE CIRC P 1,335.0 1,335.0 Circ and condition mud at 4 bpm. 10:15 12:00 1.75 SURFAC CASE RUNC P 1,335.0 2,679.0 Continue running 9 5/8" 40# L-80 BTC csg from 1335' to 2640' (69 jts total) MU FMC fluted hanger and land csg w/ FS @ 2679' & FC @ 2598' 12:00 12:30 0.50 SURFAC CASE RURD P 2,679.0 2,679.0 RD fill up tool. MU cement head and lines. 12:30 14:00 1.50 SURFAC CEMENT CIRC P 2,679.0 2,679.0 Clrc and condition mud for cement. Stage pumps from 2 - 7.5 bpm ICP 370 psi FCP 310 psi 14:00 15:45 1.75 SURFAC CEMENT PUMP P 2,679.0 2,679.0 Cemented 9 5/8"casing as follows: Pumped 40 bbls fresh water w/ Biozan as pre flush w/ nut plug as marker w/ rig pumps -Switch over to Dowell -Pumped 2 bbls water -Tested lines to 2900 psi -Dropped btm plug - Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 4.4 BPM @ 256 psi -Mixed & pumped 293 bbls 10.7 ppg Lead slurry (ASL) @ 6.3 BPM @ 265 psi Observed nut plug marker @ shakers w/ 270 bbls lead slurry pumped -pumped down surge can) Switched to tail slurry -Mixed & pumped 47 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 6.0 BPM @ 175 psi 15:45 16:30 0.75 SURFAC CEMENT DISP P 2,679.0 2,679.0 Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 179.5 bbls 9.9 ppg mud @ 7.5 BPM @ 300 to 837 psi slowed pump to 4.0 BPM (for the last 7 bbls of displacement) Bumped plug w/ 1200 psi -Check floats OK - CIP @ 1616 hrs. -Full circulation throughout job w/ 100 bbls 10.7 ppg cement returns to surface -reciprocated pipe during circulating & into cement job to 50 bbls of displacement -hole getting sticky -landed casing for remainder of job 16:30 17:30 1.00 SURFAC CEMENT OTHR P 2,679.0 2,679.0 RU & test 9 5/8" csg to 2500 psi for 30 mions. - RD - Blow down lines Latest BOP Test Data _ _ _ Date Comment Page 1/2 Report Printed: 12/28/2006 Security Level: Development Time Log tig: DOYON Doyon Daily Drilling Report CD3-302 Report Number: 4 Report Date: 2/4/2006 ~ I ~ iiroe ~' Depth Start I~~~ ~h Fs" T ; c ... - Ph ase i~ Code i OpSul .,~. ~. F'-N-T Trbl Code ~ l ~h' Ch;s ~' '>iKB) iIF~L' ~ ~ ~~ Com~r.~Q~_:a~ rn 17:30 18:30 1.00 SURFAC CEMENT RURD P 2,679.0 2,679.0 RD cement equipment - LD landing jt. 18:30 22:30 4.00 SURFAC WELCTL NUND P 2,679.0 2,679.0 ND surface riser & starting head - NU csg head & test to 1000 psi - NU BOPE 22:30 00:00 1.50 SURFAC WELCTL OTHR P 0.0 0.0 RU to test BOPE -fill lines Mud Check Data 1 T D~- tr _Y:B~ Den t _~,., ~ b tl ~ ype p FVC-is ~,cp _ -- YF i`,aic Gel (10.,~ Gel (10m1 ~ I ~~ ~ ~ rr ~ ~ nr, li ~ Drn d il_t 1Gi `t? (Ibf1100ft ) Irf1 ~Ofl". if _- i ~ fADT I~~lubl) I p y lernp .r i Cor...~ Spud Mud 2,689.0 5.50 b3 15.0 4.000 4.000 10.5 0.0 9.0 12.000 4.000 4.5 Spud Mud 2,689.0 10.00 300 27.0 56.000 66.000 72.000 73.000 11.4 0.0 9.0 4.7 - - Drill Strin s: BHA No. 1 -BHA #1`'Surface Hole / Bit - - - Run No. 1 - 12 1/4in, HUGHES-CHR, MXL-1, 5040435 - _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (l32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WUB (min) (1000... 114.0 2,689.0 0.75 16/16/18/12 4-6-WT-G-E-2-NO-TD 60 35 35 Drill Strin Components _ Jts Item Description OC "rl'- D (in) Top Conn Sz (in) Top Thread Cum Len ~, fU 24 Drill Pipe -Heavy Wgt __ 5 3.000 721.75 1 Jars 7 5/8 2.875 756.05 1 Drill Collar -NonMag 7 3/4 2.813 787.06 1 Drill Collar -NonMag 7 1/2 2.813 818.10 1 Sub -Bottom Hole Orienting 8 2.750 821.02 MWD 8 3.250 830.96 1 MWD 8 1.920 840.83 1 MWD 7.96 3.500 853.91 1 MWD 8 1.920 862.89 1 Crossover -NonMag 8 2.750 865.43 1 Stabilizer 8 2.875 871.34 1 Sub -Float 7.79 2.810 873.45 1 Mud Motor --- - - 8 5.000 902.68 S Drillln Pafamete -- - - ~ Slidin Hr um Dnll ~~ NPIA~ 1 FU HI Rni HL ~I .S H1 fl ~ ~ ' ~ ~ ' >' Sri H~G I I mmlft - B ~ ) ~ ',:w i ~ I ,li? Time ~hrs 1 ~ _ ) ~ 1 ~_ b~ i 1 ~ Lf ~ Oif 8tm f~ ~ si r N ~f p ~ WOB Ibf i~ ~ ! P ~ ~ r~ _ In I Tq -- 2 60 ~-0 1,5!5.00 15.18 2,689.01 ~_ L 2 0 6 _ _51 I ~a00 - ~ X50 0 -_ Cement Surface Casin -Started 2/4/2005 Type Wellbore String Cement Evaluation Results casing CD3-302PB1 Bond log run (Y/N): N Remedial cement required (Y/N): N Test pressure (psi): 2500 Test time (hrs): 30 Top of cement sufficient (Y/N): N Stg No. Description Top (ftKB) Bottom (ftK6) O (end) (bbl/... P (final) (psi) 1 Cement Casing 0.0 2,679.0 4 610.0 ~~~.r_~ 1 Class I , ur ~ ,sacks) ~ V ;obl) Density QWgap Wield (ft /sad.° Est Top,(ftKBj __ FstBtm (ftK6 FLUSH 0 40.0 8.30 G.00 Spacer 0 50.0 10.50 0.00 LEAD 397 412.0 10.70 4.45 0.0 2,179.0 TAIL G 235 49.0 15.80 1.17 2,179.0 2,679.0 Page 2/2 Report Printed: 12/28/2008 Well Name: CD3-302 Rig: Drilling Supervisor: Lutrick /Mickey Type of Test: Casing Shoe Test LOT/FIT Hole Size: $-3/4" ~ Casin Shoe Dept RKB-CHF: 36.9 Ft 2679.0 Ft-MD 2505.0 Casing Size and Description: 9-5/8" 40#/Ft L-80 BT Casin Test Mud Weight: 9.9 ppg PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 2/4/2006 Volume Input Volume/Stroke Pum Rate: Pump used: #2 Mud Pump ~ Strokes ~ 0.1005 Bbls/Strk ~ 8.00 Strk/min ~ ~ Pumping down annulus and DP. ~ Casln Test Pressure Inte rit Test Hole De th Pumpin Shut-in Pumpin Shut-in Ft-TVD 2709.0 Ft-MD 2530.0 Ft-TVD Strks si Min psi Strks si Min psi ~ 0 25 0 2550 0 0 0.00 1100 Pressure IntegrityTest 2 175 1 2550 1 20 0.25 1080 h ~ Mud 10 min Gel: 4.0 Lb/100 Ft2 Mud 10 min Gel: Test Pressure: 2500.0 psi Rotating Weight: Rotating Weight: 75000.0 Lbs Blocks/Top Drive Weight: Blocks/Top Drive Weight 75000.0 Lbs Desired PIT EMW: Estimates for Test: 1.9 bbls Estimates for Test: EMW =Leak-off Pressure + Mud Weight = 1100 + g 6 ppg 4 ~UU 1 1545 Lb/100 Ft2 6 505 3 2540 Lbs 8 680 4 2540 Lbs 10 890 5 2540 ppg 12 1125 6 2535 psi 0.8 bbls 14 1340 7 2535 ~~ 16 1520 8 2535 0.052 x TVD 0.052 x 2505 Shut-in Pressu EMW at 2679 Ft-MD (2505 Ft-ND) = 18.0 1080 0 3000 zsoo zooo w y 1 soo w a 1000 500 0 Lost 25 psi dunng test, held 99% of test pressure. 22 2230 15 2530 24 2490 20 2530 24.5 2550 25 2530 4 300 ~ 1. 5 410E 5 410 2. 81 61011 3. 11 820 5.00 870 12 880 5.50 860 13 950 6.00 860 I I II I II 161 110011 7.501 8401 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ~~CASING TEST --LEAK-OFF TEST O PIT Point Pum ed Bled Back PUm ed Bled Back s s s s Tested 9 5/8" csg after bumping plug on cmt job Summary • i Note to File CD3-111 (206-030...307-066) Colville River Unit (Fiord-Nechelik) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 106 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 76% XS of the calculated hole volume. -- On the initial leak off test, there are two pressure slopes. The inflection occurs at about 14.1 EMW. With continued pumping an ultimate FIT of 17.4 EMW was reached when the pressure drops back to 16.3 EMW. Two slopes are not unusual and have been seen on other CD3 wells. Minimal fluid was pumped in. The pressure declined during the observation period to about 13.5 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run. and successfully cemented. Full returns were noted and the casing was reciprocated. Sufficient cement was pumped to place cement above the shallower Kuparuk sand. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 14.6 EMW, only slightly less than the bleed-off pressure on the initial test. The pressure declined with additional pumping to 13.7 EMW. During the observation period, the pressure declined to 12.7 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD3-111. The surface shoe of CD3-112 is about 530' distant. An examination of the cementing and pumping information for this well did not reveal any problem that would preclude granting CPAI's request for CD3-111. There are 4 other wells between 740 - 1100'. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Tom Maunder, PE Sr. Petroleum Engineer February 19, 2007 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070219--CD3-1 l l.doc • . Note to File CRU CD3-111 (PTD 2060300) February 16, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling. Wastes within Well CD3-111 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of CD3-111. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set at a true vertical depth subsea ("TVDSS") of about 2,432', near the base of a 400- to 500-foot thick claystone and siltstone interval that persists throughout the area This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of Colville River Unit ("CRU") CD3-111 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 105' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Nechelik No. 1 ("Nechelik 1"), CD3-112, CD3-108, and Fiord No. 5 ("Fiord 5"). The discussion that follows is based on well logs from these wells and on mud logs recorded in Nechelik 1 and Fiord 5. An index map and a structural cross- section are provided, below. The proposed injection interval in CRU CD3-111 lies in the Seabee formation near the center of Section 5, T12N, RSE, UM and about 2-1/2 miles from the current boundary of the CRU. The 9-5/8" surface casing shoe of CD3-111 lies at a depth of about 2,432' TVDSS, near the base of a 400' to 500' thick interval that is dominated by claystone and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to be at about 6,515' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 23' thick interval of silty sandstone that lies between 2,517' and 2,540' TVDSS, which is just below the surface casing shoe. This sandstone is part of a 177' thick interval of siltstone, sandy siltstone and silty sandstone interval that extends from 2,495' to 2,672' TVDSS. Two underlying siltstone and sandy siltstone zones may also accept some of the injected fluids. These zones lie between 2,732' and 2,795' TVDSS and 2,848' and 2,908' TVDSS. The aggregate thickness of all of these potential injection zones is about 400'. These three potential • CRU CD3-111 Note to File • February 16, 2007 Page 2 of 4 injection zones are separated by two claystone intervals that are, in descending order, 59' and 53' thick. Beneath the injection zones are thick intervals of thinly interbedded siltstone and claystone that appear to be continuous throughout the area. These interbedded siltstone and claystone layers will provide lower confinement for any injected wastes. ,, __l Unit ~~- CD3.,OBCO ~ ~ boundary ~ 1 qqq°°''°B ~ CD3-170 CD3-117 ~ I CONF CD}7, CONF '-- -- _ C -112 ONF SPS Fiord 5 :, '~ D}302 CD}307 j ~ \ \~~ / D3302 PB7 is / P , ~I -108 CD3-112 }~~~ ~. ~, cn3-1 i i Injection Interval ,s ,, L Nechelik 1 z I Index Map The operator's application reports the base of permafrost occurs at about 1,600' TVDSS in this area. Inspection of the well logs from Nechelik 1 and Fiord 5 indicates that precise determination of the base of permafrost is difficult here. The geologic section is frozen through about 1,100' TVDSS in Nechelik 1, which lies 2-1/2 miles southwest, and about 1,400' TVDSS in Fiord 5, which lies 1-1/2 miles northeast. The base of permafrost lies more than 1,100' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD3-111 likely contains methane gas. Records from Nechelik 1 and Fiord 5 indicate that traces of methane were first measured 245' and 80' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (range: 9.7 to 10.2 pounds per gallon). The shallowest occurrence of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 890' and 1,325' TVDSS, respectively. So, the entire proposed disposal zone likely contains methane gas. Supporting documentation to ConocoPhillips' annular disposal application states: '`There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area injection Order No. 30, which governs the Fiord Oil Pool, states '`There are no underground sources of drinking water beneath the permafrost within the proposed affected area" which includes the area that will be influenced by annular disposal operations in CD3-111. [n addition, Area Injection Order 18B, which governs the CRU also states that there are no USDWs beneath the permafrost within the area. • • CRU CD3-111 February 16, 2007 Note to File Page 3 of 4 The shallowest oil shows occur in Fiord 5 from about 4,000' to 4,080' and from 4,130' to 4,250' TVDSS, well below the likely injection zones for any waste injected into the annulus of CD3-1 11. In Nechelik I, the shallowest oil show was encountered at about 2,330' TVDSS, and it was rated as fair by the mud- Nechelik 1 CD3-112 CD3-111 CD3-108 --Fior~l.~ .. ~£ _ ~ ~ x ~ ~ ~~ r .~ Ma ~; r+ _ ~ ~ ~ ~ ~ i ,m ~ ~ ~ ~ \~l)~ ~. -.. ~., 41 ~.. _. Tea.,. i '. - V~, -- d - C ~.. i t li '~:.... 'i ~ _.. a ~ e ~` ~ P ~~r-- ~ Permafrost = - ~' ~ - - ~ ~ __ ~~ ~~ s_ -_ ~ ~ _ r '~ - S ~_ ~-_ - ~ - f -;~ ~ _ . _ _ . - - ~~; ; ~~ ; -- - __ ~ ~ -' ~ - I _-- 4. ;_ 3 ~ to - - zt ~~ _ ~ ~ r Surface ~ - ~_ ~ ~ I.:.;~ _~ "Fair od~ ~ ~ Most Likely ?et~t sbow~ _~~ ,x ~ ;~f Inject-an - ~C g hoe. ~/ - F~ -- - r ice. w 2 ~.. .~ ~ S ? - ~ i oitys .w~ ~ ~ ~ . ~ f ossible ~ ~ ~,. ~ 1 "Trace ~ _~ > ~~~ ~ ~,.~ ~ P _ ~^z~ _ ± ~~ - } 1~_ r Injection E ~ ~ ~ a *~, i m ~~ ~ ~ ~ _ ~~'~ ~ ~ Zones --- _ , x ~ 3 ~ $i .~ ~ ;: ~ ~.~ ~. °~ _ i _ _ - _ ~ > .... - - - r wed _ ..Fair" oil ~ .. ~ _-_ 3 _- _- f s ~ shows FL__.. ~_ ,' _ Y --t- - begin Southwest to Northeast Structural Cross-section C~ CRU CD3-1 l l Note to File • February 16, 2007 Page 4 of 4 logging geologist. Additional trace amounts of oil were observed at about 2,725,' 3,000,' 3,375' to 3,575,' 3,800' to 3,875,' 3,950' to 4,000,' and 4,075' to 4,350' TVDSS. Examination of well logs from Nechelik 1 and CD3-11 1 do not indicate the presence of commercial oil or gas reservoirs in the intervals that will be influenced by the proposed annular disposal operations. The following chart provides an estimate of the affected area surrounding the CD3-111 wellbore. Assuming a 23' thick injection zone with 25% porosity and a maximum of 35,000 barrels of injected waste, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of about l05' from the wellbore. Injected Fluid vs Affected Distance from CD3-111 Wellbore (assumes 23' thick zone having 25% porosity) 150 ~ m m m 0 100 a d E 0 m c a O ~ 50 v d Q _ _.-- .. :.--- .. ~ __ - -+'` I 0 ~" - -------- 0 5,000 10,000 15,000 20,000 Amount of Injected Fluid (barrels) i 25,000 30,000 35,000 The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 1,000' of permafrost, and is bounded above and below by continuous layers of claystone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations. The proposed injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. [ reco end approval of this annular disposal project. Steve Davtes 2'' ~~ ' ~ ~ Senior Petroleum Geologist RE: FW: Alpine CD3-111 SSSV Control Line Subject: RE: F~V': Alpine CD3-11 1 SSSV Control Line From: NSK ~~%cll inte~~rity Proj <N1878@conocophillips.com> Date: 1lon, ? 1 .Auk ?O06 C1~:4?:? ; -0800 To: Thomas Maunder atom_maunder~i;admin.state.~~.tis% Yes, that is correct. The test was performed by the slickline crew that installed it. After they run the SSSV the well is put in service under flowing conditions, then is tripped to verify it works. This should not be construed as an official SVS test, but is a functional checkout. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, August 21, 2006 7:34 AM To: NSK Well Integrity Proj Subject: Re: FW: Alpine CD3-111 SSSV Control Line Jerry, Glad the control line problem went away. What do you mean by a "flow test"? Is that that same as a SSSV test? Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 8/19/2006 8:51 AM: Tom: This note is to confirm that Alpine well CD3-111 (PTD 206-030) is back in service with a fully functional SSSV. On 8/18/06 slickline pulled the isolation sleeve and verified the function of the SSSV. A successful flow test was performed. Let me know if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: NSK Well Integrity Proj Sent: Wednesday, August 02, 2006 11:13 AM To: 'Thomas Maunder' Cc: ALP DS Lead/Simops Coord; Kralick, Jack T; Walker, Jack A; NSK Problem Well Supv Subject: RE: Alpine CD3-111 SSSV Control Line Tom: Thanks for the notice. If this becomes a bigger problem than we currently expect we will be in touch for a path forward. We will start the clock on startup day. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 1 of 2 8/21/2006 9:24 AM RE: FW: Alpine CD3-111 SSSV Control Line -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, August 02, 2006 10:57 AM To: NSK Well Integrity Proj Cc: jim_regg@admin.state.ak.us; ALP DS Lead/Simops Coord; Kralick, Jack T; NSK Problem Well Supv; NSK Prod Engr Tech Subject: Re: Alpine CD3-111 SSSV Control Line Jerry, et al, What you propose is acceptable, however for not more than 14 days. 14 days is the interval allowed when a well equipped with both a SSV and SCSSV has one valve fail. Since startup is occurring, I presume the pad will have operator type people there while CD3-111 is operating with one valve. Call or message with any questions. Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 7/30/2006 10:01 AM: Tom: Alpine well CD3-111 (PTD 206-030) has been identified to have a problem with the SSSV hydraulic control line. The line is suspected to have some water contamination that has froze preventing the valve from operating correctly. The SSSV is currently being held in the open position with a sleeve insert in the landing nipple. The well is not yet in service since the pad has not been started, so the well is cold and troubleshooting has not been completed. Operations is concerned about SVS compliance during startup on the well since the valve is not operational. To complete diagnostics the well must be flowing and warm to verify that the problem is due to ice in the line. ConocoPhillips is requesting approval to flow CD3-111 with a defeated SSSV for a period not to exceed 30 days from startup. This should provide ample time to determine the problem and find a solution. Assuming the problem is found and remedied, the well will be ready for SVS testing in September. Please let me know if this is acceptable. Thanks for your attention to this matter. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 2 of 2 8/21/2006 9:24 AM • 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, AK-MW-4254172 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20526-00. ~~~~ JUN 0 8 2006 ~_ Oll & Gass Cons. Commission Anchorage • ConocoPhillips May 30, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~; Subject: Well Completion Reports for CD3-111 and CD3-111 L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Alpine wells CD3-111 and CD3-111 L1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ,,_ ~_ ~' ~, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~, M ~. .- • STATE OF ALASKA . 1i,~ ~t ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Ar;l'~D L~+~ ' - 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1 b. Well Class: ' = Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 25, 2006 12. Permit to Drill Number: 206-030 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 6, 2006 13. API Number: 50-103-20526-00 " 4a. Location of Well (Governmental Section): Surface: 1334' FSL, 874' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: March 19, 2006 ~ 14. Well Name and Number: CD3-111 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: 331' FSL, 1566' FWL, Sec. 30, T13N, R5E, UM 9. Plug Back Depth (MD + ND): 15073' MD / 6908' ND Fiord Nechelik Oil Pool F°j~'r ~~~~ ~°~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388169 • y- 6003829 Zone- 4 10. Total Depth (MD + ND): • 15073' MD / 6908' ND ~ 16. Property Designation: b~ ADL 372105, 364471, 364470 TPI: x- 386283 y- 6007991 Zone- 4 Total Depth: x- 382830 • - 6013468 - 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" 1l) 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" 1 so sx Class G 23. Pertorations 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 8660' - 15073' 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). Submit core chips; if none, state "none". -m R S SF~ JUN 2 ~ 2006 ~; :~~+ t NONE f ~~~~ /I~, t -~ .°,~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~ `,Z7 p~ e ~~ ~~ 6/~/0,~ ~L. 2a. is. 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 Nechelik 8571' 6919' N/A 30. LIST OF ATTACHMENTS Summary of Daily 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 Alv rd Title: Alpine Area Drilling Team Leader ~(~ / ~~ cA "' Signature Phone Z~, ,~ _ ~ ~ ~ ~ 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 SLICKLINETQOLS-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 Company • Global Report Company: GonocoPhillips Alaska Inc. Field: Colville River Unit Date: 4!10/2006 Time: 11:24:58 Pagc: 1 Co-ordinatc(NE) Reference: Well: CD3-111, True North Site: Alpine CD3 ! Well: CD3-111 Vertical (TVD) Reference: CD3-111: 49.4 Section (VS) Reference: Well (O.OON,O.OOE,330.16Azi) Wellpath: CD3-111 Survey Calculation Method: Minimum Curvature ~ Db: Oracle Survey: Start Date: ~i Company: Engineer: Tool: Tied-to: Field: Colville River Unit i North Slope Alaska United States ' i 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 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True i Ground Level: 0.00 ft Grid Convergence: 0.00 deg ~' Well: CD3-111 Slot Name: j 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: CD3-111 Drilled From: Well Ref. Point ! 501032052600 Tie-on Depth: 36.10 ft ~ Current Datum: CD3-111: H eight 49.40 ft Above System Da tum: Mean Sea Level ~ Magnetic Data: 3/3/2006 Field Strength: 57513 nT Declination: Mag Dip Angle: 23.50 deg 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' ft ft ft deg ~ 36.10 0.00 0.00 330.16 Survey Program for Definitive Wellpath ~~ Date: 3/13/2006 Validated: No Version: 7 I Actual From To Survey Toolcode Tool Name ft ft 81.00 442.00 CD3-111 gyro (81.00-442 .00) CB-GYRO-SS Camera based gyro single shot i 568.95 15036.25 CD3-111 (568.95-15036.25) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey '11D Inc! :1zim T~'D S ~•s TVD N/S E/W MapN MapE Tool deg deg ft ft ft ft ft ft I 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 i, 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 i 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 i 1599.99 25.99 340.64 1547.14 1497.74 290.72 -120.67 6004121.42 388052.86 MWD+IFR-AK-CAZ-SC • Halliburton Company, Global Report Company: ' ConocoPhillipsAlaska Inc. Field: Colv ille River Unit Site: Alpine CD3 Well: CD3 -111 W'cllpath: CD3 -111 Survcv MD Inc! lzim TVD Sys'Iti'D ft deg deg ft ft 1694.42 28.42 340.75 1631. 12 1581. 72 1789.95 30.43 339.62 1714. 32 1664. 92 1884.71 32.52 338.90 1795. 13 1745. 73 1978.83 35.51 337.25 1873. 14 1823. 74 2075.23 37.24 336.37 1950. 76 1901. 36 2169.98 38.56 337.20 2025. 52 1976. 12 2265.75 39.59 337.61 2099. 87 2050. 47 2360.96 38.21 336.46 2173. 96 2124. 56 2456.29 35.92 337.00 2250. 03 2200. 63 2550.00 32.87 337.28 2327. 35 2277. 95 2646.36 34.16 336.08 2407. 68 2358. 28 2684.10 34.24 336.1.2 2438. 90 2389. 50 2726.67 34.78 336.27 2473. 98 2424. 58 2821.73 34.49 337.30 2552. 19 2502. 79 2917.22 34.31 334.83 2630. 99 2581. 59 3012.84 34.44 336.05 2709. 91 2660. 51 3108.26 33.59 334.18 2789. 00 2739. 60 3203.77 34.14 334.38 2868. 31 2818. 91 3299.28 34.97 333.35 2946. 97 2897. 57 3394.52 34.76 332.94 3025. 11 2975. 71 3490.05 33.87 334.78 3104. 02 3054. 62 3585.67 33.00 333.11 3183. 81 3134. 41 3681.13 32.38 335.78 3264. 16 3214. 76 3776.66 32.22 336.67 3344. 91 3295. 51 3872.05 33.33 338.81 3425. 11 3375. 71 3967.19 34.03 338.13 3504. 28 3454. 88 4062.69 34.96 336.85 3582. 99 3533. 59 4158.14 35.56 336.47 3660. 93 3611. 53 4253.58 35.42 336.71 3738. 64 3689. 24 4348.45 34.60 334.36 3816. 35 3766. 95 4444.43 34.59 332.55 3895. 36 3845. 96 4539.88 34.16 333.03 3974. 14 3924. 74 4635.21 33.41 332.06 4053. 37 4003. 97 4730.86 33.32 334.10 4133. 26 4083. 86 4826.48 33.02 335.41 4213. 30 4163. 90 4921.57 33.40 335.55 4292. 86 4243. 46 5016.94 33.65 336.89 4372. 36 4322. 96 5112.33 33.35 335.88 4451. 91 4402. 51 5207.59 34.10 337.09 4531. 13 4481. 73 5303.06 33.87 336.66 4610. 30 4560. 90 5397.98 34.16 337.33 4688. 98 4639. 58 5491.55 34.36 336.94 4766. 31 4716. 91 5587.78 34.16 337.16 4845. 84 4796. 44 5683.93 33.74 335.99 4925. 60 4876. 20 5779.93 33.83 335.36 5005. 39 4955. 99 5875.59 34.50 336.55 5084. 54 5035. 14 5968.84 34.35 336.29 5161. 46 5112. 06 6066.05 33.42 335.81 5242. 16 5192. 76 6161.28 33.40 334.19 5321. 66 5272. 26 6256.72 34.35 334.45 5400. 90 5351. 50 6351.54 35.32 333.37 5478. 72 5429. 32 6447.11 34.95 333.70 5556. 88 5507. 48 Date: 4!1012006 Time: 11:24:58 Page: 2 j Co-ordinate(NE) Reference: Well: CD3-111, True North Vertical (TVD) Reference: CD3-111: 49.4 Section (VS) Reference: Well (O.OON,O.OOE,330.16Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S E/W AIapN MapE Tool - ft ft ft ft 331.46 -134.94 6004162.37 388039.21 MWD+IFR-AK-CAZ-SC 375.61 -150.87 6004206.74 388023.95 MWD+IFR-AK-CAZ-SC 421.87 -168.39 6004253.26 388007.12 MWD+IFR-AK-CAZ-SC 470.69 -188.08 6004302.37 387988.17 MWD+IFR-AK-CAZ-SC I 523.24 -210.60 6004355.24 387966.44 MWD+IFR-AK-CAZ-SC 576.73 -233.53 6004409.06 387944.31 MWD+IFR-AK-CAZ-SC 632.46 -256.72 6004465.13 387921.96 MWD+IFR-AK-CAZ-SC I 687.51 -280.04 6004520.52 387899.47 MWD+IFR-AK-CAZ-SC 740.29 -302.75 6004573.63 387877.56 MWD+IFR-AK-CAZ-SC 789.06 -323.31 6004622.70 387857.73 MWD+IFR-AK-CAZ-SC 837.91 -344.38 6004671.86 387837.40 MWD+IFR-AK-CAZ-SC 857.31 -352.98 6004691.37 387829.09 MWD+iFR-AK-CAZ-SC 879.37 -362.71 6004713.58 387819.69 I MWD+IFR-AK-CAZ-SC 929.02 -384.01 6004763.54 387799.14 MWD+IFR-AK-CAZ-SC 978.32 -405.89 6004813.16 387778.01 MWD+IFR-AK-CAZ-SC 1027.43 -428.33 6004862.59 387756.31 MWD+IFR-AK-CAZ-SC 1075.85 -450.78 6004911.34 387734.59 MWD+IFR-AK-CAZ-SC 1123.80 -473.87 6004959.62 387712.21 MWD+IFR-AK-CAZ-SC I, 1172.43 -497.74 6005008.60 387689.08 MWD+IFR-AK-CAZ-SC I 1221.00 -522.33 6005057.53 387665.22 MWD+IFR-AK-CAZ-SC 1269.33 -546.07 6005106.21 387642.22 MWD+IFR-AK-CAZ-SC 1316.67 -569.20 6005153.88 387619.80 MWD+IFR-AK-CAZ-SC 1363.16 -591.44 6005200.70 387598.25 MWD+IFR-AK-CAZ-SC 1409.88 -612.02 6005247.72 387578.38 MWD+IFR-AK-CAZ-SC 1457.67 -631.57 6005295.79 387559.55 MWD+IFR-AK-CAZ-SC 1506.74 -650.93 6005345.14 387540.93 MWD+IFR-AK-CAZ-SC 1556.70 -671.64 6005395.40 387520.97 MWD+IFR-AK-CAZ-SC ~, I 1607.29 -693.47 6005446.31 387499.90 MWD+IFR-AK-CAZ-SC 1658.14 -715.49 6005497.48 387478.65 MWD+IFR-AK-CAZ-SC ~ 1707.68 -738.02 6005547.35 387456.87 MWD+IFR-AK-CAZ-SC 1756.42 -762.37 6005596.45 387433.25 MWD+IFR-AK-CAZ-SC ~, 1804.35 -787.01 6005644.73 387409.33 MWD+IFR-AK-CAZ-SC 1851.39 -811.45 6005692.13 387385.61 MWD+IFR-AK-CAZ-SC 1898.29 -835.26 6005739.38 387362.50 MWD+IFR-AK-CAZ-SC 1945.61 -857.57 6005787.02 387340.90 MWD+IFR-AK-CAZ-SC 1992.99 -879.19 6005834.72 387320.00 MWD+IFR-AK-CAZ-SC 2041.19 -900.42 6005883.22 387299.49 MWD+IFR-AK-CAZ-SC 2089.43 -921.51 6005931.77 387279.13 MWD+IFR-AK-CAZ-SC I 2137.93 -942.61 6005980.57 387258.76 MWD+IFR-AK-CAZ-SC i 2187.00 -963.57 6006029.95 387238.54 MWD+IFR-AK-CAZ-SC 2235.88 -984.32 6006079.13 387218.53 MWD+IFR-AK-CAZ-SC ~ 2284.41 -1004.78 6006127.96 387198.79 MWD+IFR-AK-CAZ-SC ~~ i 2334.30 -1025.91 6006178.15 387178.42 MWD+IFR-AK-CAZ-SC 2383.57 -1047.25 6006227.73 387157.82 MWD+IFR-AK-CAZ-SC 2432.21 -1069.24 6006276.70 387136.56 MWD+IFR-AK-CAZ-SC , 2481.27 -1091.12 6006326.07 387115.42 I MWD+IFR-AK-CAZ-SC 2529.59 -1112.21 6006374.70 387095.06 MWD+IFR-AK-CAZ-SC 2579.12 -1134.21 6006424.55 387073.81 MWD+IFR-AK-CAZ-SC 2626.64 -1156.37 6006472.39 387052.37 MWD+IFR-AK-CAZ-SC 2674.58 -1179.42 6006520.67 387030.04 MWD+IFR-AK-CAZ-SC 2723.22 -1203.24 6006569.65 387006.95 MWD+IFR-AK-CAZ-SC j 2772.45 -1227.76 6006619.25 386983.18 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report - Company: ConocoPhillipsAlaska Inc. Date: 4/10/2006 ' Time 11'24'58 Pager 3 Field: Colville River Unit Co-ordinatc(NE) Reference: Well: CD3-111, True North Site: Alpine CD3 Vertical (TVD) Reference: CD3-111: 49:4 .Well: CD3-111 Section (VS) Reference: Well (O.OON,O.OOE,330.16Azi) J '1'ellpath: CD3-111 Survey Calculation Dlethod: Minimum Curvature Db: Oracle Survey MD Incl Azim T~'D ' Sys T~'D N/S E/~V AfapN IV1apE Tool ft deg deg ft ft tt ft ft ft 6542.67 34.62 333 .58 5635.36 5585 .96 2821.30 -1251 .96 6006668 .45 386959.71 MWD+IFR-AK-CAZ-SC 6638.37 35.03 334 .15 5713.92 5664 .52 2870.37 -1276 .03 6006717 .86 386936.38 MWD+IFR-AK-CAZ-SC 6733.77 35.03 335 .59 5792.04 5742. 64 2919.94 -1299 .29 6006767 .78 386913.87 MWD+IFR-AK-CAZ-SC 6829.22 34.11 335 .26 5870.64 5821. 24 2969.19 -1321 .81 6006817 .36 386892.09 MWD+IFR-AK-CAZ-SC 6924.72 34.56 334 .84 5949.50 5900. 10 3018.03 -1344 .53 6006866 .52 386870.10 MWD+IFR-AK-CAZ-SC 7020.10 34.40 334 .16 6028.12 5978. 72 3066.77 -1367 .78 6006915 .60 386847.59 __ MWD+IFR-AK-CAZ-SC 7115.62 34.80 335 .78 6106.75 6057. 35 3115.91 -1390 .72 6006965 .08 386825.39 MWD+IFR-AK-CAZ-SC 7211.32 34.24 334 .53 6185.60 6136. 20 3165.12 -1413 .50 6007014 .62 386803.35 MWD+IFR-AK-CAZ-SC 7304.54 36.73 332 .98 6261.50 6212. 10 3213.64 -1437 .45 6007063 .49 386780.14 MWD+IFR-AK-CAZ-SC 7402.02 41.06 332 .81 6337.35 6287. 95 3268.11 -1465 .33 6007118 .36 386753.07 MWD+IFR-AK-CAZ-SC 7497.95 45.72 333 .03 6407.05 6357. 65 3326.77 -1495 .32 6007177 .46 386723.97 MWD+IFR-AK-CAZ-SC 7593.32 47.19 332 .19 6472.75 6423. 35 3388.15 -1527 .12 6007239 .30 386693.09 MWD+iFR-AK-CAZ-SC 7687.73 50.43 332 .63 6534.91 6485. 51 3451.11 -1560 .02 6007302 .74 386661.15 MWD+IFR-AK-CAZ-SC 7784.11 53.01 332 .22 6594.62 6545. 22 3518.16 -1595 .04 6007370 .31 386627.13 MWD+IFR-AK-CAZ-SC 7879.52 56.50 331 .03 6649.67 6600. 27 3586.70 -1632 .08 6007439 .39 386591.13 MWD+IFR-AK-CAZ-SC 7975.00 59.46 331 .01 6700.29 6650. 89 3657.51 -1671 .30 6007510 .77 386552.98 MWD+IFR-AK-CAZ-SC 8069.05 61.45 330 .70 6746.66 6697. 26 3728.97 -1711 .15 6007582 .81 386514.21 MWD+IFR-AK-CAZ-SC 8165.97 64.42 330 .39 6790.76 6741. 36 3804.11 -1753 .59 6007658 .57 386472.90 MWD+IFR-AK-CAZ-SC 8259.93 67.38 329 .63 6829.12 6779. 72 3878.38 -1796 .46 6007733 .47 386431.15 MWD+IFR-AK-CAZ-SC 8356.45 70.43 329 .76 6863.85 6814. 45 3956.12 -1841 .89 6007811 .88 386386.89 MWD+IFR-AK-CAZ-SC 8452.09 73.67 328 .77 6893.33 6843. 93 4034.31 -1888 .39 6007890 .75 386341.57 MWD+IFR-AK-CAZ-SC 8547.27 78.57 328 .96 6916.15 6866. 75 4113.38 -1936 .15 6007970 .51 386295.01 MWD+IFR-AK-CAZ-SC 8642.12 84.13 329 .33 6930.41 6881. 01 4193.85 -1984 .22 6008051 .69 386248.15 MWD+IFR-AK-CAZ-SC 8737.04 86.23 331 .50 6938.39 6888. 99 4276.09 -2030 .91 6008134 .62 386202.70 MWD+IFR-AK-CAZ-SC 8832.94' 86.93 330. 13 6944.11 6894. 71 4359.66 -2077 .59 6008218 .87 386157.28 MWD+IFR-AK-CAZ-SC 8928.47 86.86 329. 07 6949.28 6899. 88 4441.94 -2125 .86 6008301 .85 386110.26 MWD+IFR-AK-CAZ-SC 9023.96 87.11 326. 42 6954.31 6904. 91 4522.57 -2176 .75 6008383. 23 386060.59 MWD+IFR-AK-CAZ-SC 9119.36 90.14 323. 70 6956.60 6907. 20 4600.74 -2231 .36 6008462. 20 386007.16 MWD+IFR-AK-CAZ-SC 9214.38 91.00 321. 89 6955.65 6906. 25 4676.41 -2288 .81 6008538. 72 385950.85 MWD+IFR-AK-CAZ-SC 9308.47 91.31 322. 35 6953.75 6904. 35 4750.66 -2346 .57 6008613. 82 385894.22 MWD+IFR-AK-CAZ-SC 9405.05 90.94 320. 74 6951.86 6902. 46 4826.27 -2406 .62 6008690. 32 385835.31 MWD+IFR-AK-CAZ-SC 9498.91 92.79 322. 55 6948.80 6899. 40 4899.83 -2464 .83 6008764. 73 385778.22 MWD+IFR-AK-CAZ-SC 9595.79 91.80 322. 19 6944.92 6895. 52 4976.50 -2523 .93 6008842. 27 385720.27 MWD+IFR-AK-CAZ-SC 9690.52 91.80 323. 10 6941.95 6892. 55 5051.76 -2581 .38 6008918. 38 385663.96 MWD+IFR-AK-CAZ-SC 9785.32 90.57 323. 93 6939.99 6890. 59 5127.96 -2637. 74 6008995. 41 385608.76 MWD+IFR-AK-CAZ-SC 9881.99 92.11 324. 01 6937.73 6888. 33 5206.11 -2694. 58 6009074. 40 385553.10 MWD+IFR-AK-CAZ-SC 9977.31 92.60 324. 55 6933.81 6884. 41 5283.44 -2750. 18 6009152. 54 385498.66 MWD+IFR-AK-CAZ-SC 10073.19 93.85 325. 46 6928.42 6879. 02 5361.85 -2805. 08 6009231. 76 385444.95 MWD+IFR-AK-CAZ-SC 10168.29 91.49 322. 28 6923.99 6874. 59 5438.56 -2861. 09 6009309. 30 385390.11 MWD+IFR-AK-CAZ-SC 10261.66 92.72 322. 82 6920.56 6871. 16 5512.64 -2917. 82 6009384. 20 385334.49 MWD+IFR-AK-CAZ-SC 10359.12 91.67 322. 76 6916.82 6867. 42 5590.20 -2976. 71 6009462. 63 385276.77 MWD+IFR-AK-CAZ-SC 10454.59 90.44 322. 84 6915.07 6865. 67 5666.23 -3034. 43 6009539. 51 385220.21 MWD+IFR-AK-CAZ-SC 10549.88 92.36 323. 14 6912.74 6863. 34 5742.30 -3091. 77 6009616. 42 385164.02 MWD+IFR-AK-CAZ-SC 10645.85 91.61 324. 65 6909.41 6860. 01 5819.78 -3148. 28 6009694. 74 385108.68 MWD+IFR-AK-CAZ-SC '! 10741.25 89.64 324. 74 6908.37 6858. 97 5897.63 -3203. 41 6009773. 40 385054.73 MWD+IFR-AK-CAZ-SC 10836.62 89.70 325. 28 6908.92 6859. 52 5975.76 -3258. 10 6009852. 33 385001.22 MWD+IFR-AK-CAZ-SC 10930.76 91.19 325. 96 6908.19 6858. 79 6053.45 -3311. 25 6009930. 80 384949.24 MWD+IFR-AK-CAZ-SC 11027.25 91.00 326. 78 6906.35 6856. 95 6133.78 -3364. 68 6010011. 91 384897.03 MWD+IFR-AK-CAZ-SC '~ 11117.19 89.46 326. 94 6905.99 6856. 59 6209.08 -3413. 85 6010087. 94 384849.00 MWD+IFR-AK-CAZ-SC 11211.68 88.65 325. 26 6907.54 6858. 14 6287.50 -3466. 54 6010167. 13 384797.49 MWD+IFR-AK-CAZ-SC 11313.07 89.21 325. 66 6909.44 6860. 04 6371.00 -3524. 02 6010251. 48 384741.28 MWD+IFR-AK-CAZ-SC 11409.06 88.10 325. 53 6911.69 6862. 29 6450.17 -3578. 24 6010331. 45 384688.25 MWD+IFR-AK-CAZ-SC 11504.26 90.51 326. 90 6912.84 6863. 44 6529.28 -3631. 17 6010411. 33 384636.52 MWD+IFR-AK-CAZ-SC • Halliburton Company Global Report ' Company: ConocoPhillips A{aska Inc. Date: 4/10!2006 `time: 11:24:58 Pager 4 '~ Field: Colville River Unit Co-ordinatc(NE) Reference: Well: CD3-111, True North Site: Alpine CD3 b'ertical (TVD) Reference: CD3-111: 49.4 ~'Vell: CD3-111 Section (VS) Reference: Well (O.OON,O.OOE,330.16Azi) ~'1'ellpath: CD3-111 Sur~~cy Calculation Method: Minimum Curvature Db: Oracle Sm-vcy 11D Inc! :>,zim TVD Sys71'D N/S E/N AIapN MapE Tool ft deg deg ft ft ft ft ft ft j I 11599.88 89.89 324. 26 6912 .51 6863.11 6608.16 -3685 .21 6010491 .00 384583 .67 MWD+IFR-AK-CAZ-SC ! i 11695.66 89. 70 322. 87 6912. 85 6863.45 6685.21 -3742 .09 6010568. 89 384527 .95 MWD+IFR-AK-CAZ-SC 11791.18 91 .43 325. 14 6911 .91 6862.51 6762.48 -3798 .22 6010646 .99 384472 .99 MWD+IFR-AK-CAZ-SC 11885.52 91. 12 324. 56 6909. 81 6860.41 6839.60 -3852 .52 6010724 .90 384419 .85 MWD+IFR-AK-CAZ-SC 11981.51 91. 24 324. 67 6907. 84 6858.44 6917.84 -3908 .10 6010803. 96 384365 .46 MWD+IFR-AK-CAZ-SC 12077.12 91. 00 322. 69 6905. 97 6856.57 6994.86 -3964 .71 6010881. 81 384310 .01 MWD+IFR-AK-CAZ-SC 12172.62 90. 57 320. 57 6904. 66 6855.26 7069.72 -4023. 98 6010957. 55 384251 .87 MWD+IFR-At<-CAZ-SC I 12267.79 89. 08 320. 80 6904. 95 6855.55 7143.35 -4084. 28 6011032. 06 384192 .69 MWD+IFR-AK-CAZ-SC 12363.56 88. 65 323. 52 6906. 85 6857.45 7218.96 -4143. 01 6011108. 54 384135 .10 MWD+IFR-AK-CAZ-SC ~ 12457.58 89. 64 322. 73 6908. 25 6858.85 7294.16 -4199. 43 6011184. 57 384079 .83 MWD+IFR-AK-CAZ-SC 12553.19 91. 62 323. 33 6907. 20 6857.80 7370.54 -4256. 92 6011261. 79 384023 .49 MWD+IFR-AK-CAZ-SC ' 12648.95 90. 32 324. 66 6905. 58 6856.18 7447.99 -4313. 20 6011340. 0% 383968. 38 MWD+iFR-AK-CAZ-SC ~ I 12744.86 91 .12 329.30 6904 .37 6854 .97 7528 .38 -4365.45 6011421 .23 383917.35 MWD+IFR-AK-CAZ-SC 12837.92 89 .89 331.63 6903 .55 6854 .15 7609 .34 -4411 .32 6011502 .86 383872.70 MWD+IFR-AK-CAZ-SC 12936.18 91 .12 329.20 6902 .68 6853 .28 7694 .77 -4459 .82 6011589 .01 383825.49 MWD+IFR-AK-CAZ-SC 13030.95 89 .70 326.40 6902 .01 6852 .61 7774 .96 -4510 .31 6011669 .93 383776.20 MWD+IFR-AK-CAZ-SC 13127.14 88 .84 326.33 6903 .23 6853 .83 7855 .03 -4563 .59 6011750 .79 383724.14 MWD+IFR-AK-CAZ-SC 13222.97 91 .18 326.67 6903 .22 6853 .82 7934 .94 -4616 .48 6011831 .47 383672.46 MWD+IFR-AK-CAZ-SC 13317.93 92 .42 326.13 6900 .23 6850 .83 8013 .99 -4669 .00 6011911 .30 383621.13 MWD+IFR-AK-CAZ-SC 13412.80 91 .49 325.61 6897 .00 6847 .60 8092 .48 -4722 .20 6011990 .56 383569.12 MWD+IFR-AK-CAZ-SC 13504.27 91 .49 328.06 6894 .62 6845 .22 8169 .01 -4772 .22- 6012067 .83 383520.26 MWD+IFR-AK-CAZ-SC 13604.13 92 .36 325.91 6891 .26 6841 .86 8252 .70 -4826 .59 6012152 .31 383467.15 MWD+IFR-AK-CAZ-SC 13698.62 92 .54 326.91 6887 .22 6837. 82 8331 .34 -4878 .82 6012231 .72 383416.11 MWD+IFR-AK-CAZ-SC 13795.22 91 .43 327.02 6883 .88 6834. 48 8412 .27 -4931 .45 6012313 .42 383364.70 MWD+IFR-AK-CAZ-SC 13889.52 91 .62 326.13 6881 .37 6831. 97 8490 .94 -4983 .37 6012392 .86 383313.96 MWD+IFR-AK-CAZ-SC 13985.03 92 .36 329.45 6878 .05 6828. 65 8571 .69 -5034 .24 6012474 .36 383264.31 MWD+IFR-AK-CAZ-SC 14080.33 91 .92 329.50 6874 .49 6825. 09 8653 .73 -5082 .62 6012557. 10 383217.18 MWD+IFR-AK-CAZ-SC 14176.56 89 .95 332.21 6872 .92 6823. 52 8737 .75 -5129 .47 6012641 .81 383171.60 MWD+IFR-AK-CAZ-SC 14272.28 91 .25 336.82 6871 .92 6822. 52 8824 .13 -5170 .64 6012728. 79 383131.73 MWD+IFR-AK-CAZ-SC 14367.67 90 .81 338.67 6870 .20 6820. 80 8912 .39 -5206 .76 6012817. 57 383096.94 MWD+IFR-AK-CAZ-SC 14463.16 88 .96 338.59 6870 .39 6820. 99 9001 .31 -5241 .55 6012907. 00 383063.48 MWD+IFR-AK-CAZ-SC 14558.76 88 .66 336.62 6872 .38 6822. 98 9089 .68 -5277 .97 6012995. 89 383028.40 MWD+IFR-AK-CAZ-SC 14653.99 87. 91 334.01 6875. 23 6825. 83 9176 .16 -5317. 71 6013082. 95 382989.95 MWD+IFR-AK-CAZ-SC 14749.43 86. 68 335.28 6879. 74 6830. 34 9262. 31 -5358. 54 6013169. 69 382950.43 MWD+IFR-AK-CAZ-SC 14845.09 85. 75 336.18 6886. 05 6836. 65 9349. 32 -5397. 77 6013257. 28 382912.51 MWD+IFR-AK-CAZ-SC 14940.52 84. 45 337.18 6894. 20 6844. 80 9436. 63 -5435. 41 6013345. 13 382876.18 MWD+IFR-AK-CAZ-SC 15036.25 83. 59 339.37 6904. 18 6854. 78 9525. 07 -5470. 65 6013434. 08 382842.27 MWD+IFR-AK-CAZ-SC 15073.00 ~ 83. 59 339.37 6908. 28 6858. 88 9559. 25 -5483. 52 6013468. 45 - 382829.92 ' PROJECTED to TD • s 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 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.10' MD Window /Kickoff Survey: 15,036.25' MD (if applicable) Projected Survey: 15,073.00' 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: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~.~ ~) t~~l (l G Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~o~_ p3v STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: dim re~~,,~:~s3aon"i:~.state.a>i.~~s• aogcc prud3oe br:~~ad:~in.state.ak.us i3~:lr :~eckenstev~(t:`I~e1Le(~'E1'3_'Jt£~,et~.a?~.L!`e Contractor: Doyon Rig No.: 19 DATE: 3/20/2006 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD3-111 PTD #206-93Q Operation: Drlg: x Workover: Test: Initial: Weekly: Test Pressure: Rams: 250/5000 Annular: 250/3500 TEST DATA MISC. INSPECTIONS: ' Test Result Test Result Location Gen.: P Well Sign P ', Housekeeping: P Drl. Rig P ' PTD On Location P Hazard Sec. P ', Standing Order Posted P BOP STACK: 'I Quantity Size Test Result '~ Annular Preventer 1 13-5/8 P i Pipe Rams 1 3-1/2x 6 P ~ Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results Explor.: Bi-Weekly x Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test R3 Upper Kelly 1 FP Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 27 P Full Pressure Attained 2 min 32 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2050 psi Number of Failures: 1 Test Time: 15 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at:~ 3-~`i )adn:i:~.state.ak.us Remarks: Auto IBOP failed, continued with the rest of the test and then changed out the auto IBOP and retested OK. 24 HOUR NOTICE GIVEN YES X NO Date 03/19/06 Time 6:OOam Test start Finish Waived By Witness Not Waived John BOP Test (for rigs) BFL 11/09/04 Doyon19 3-20-06 CD3-111.x1s ConocoPhilli S Casing Detail 9 5/8"Surface Cas-n_g • ao~-~-~ Well: CD3-111 Date: 3/8/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS gy ~ °-~13- l ' p Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 2.20 36.30 Jts 3 to 70 68 Jts 9-5/8" 40# L-80 BTC Csg 2601.57 38.50 Weatherford Float Collar 1.46 2640.07 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.17 2641.53 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 2718.70 2721.00 TD 12 1/4" Surface Hole 2731.00 12-1/4" Hole @ 2731' MD / 2477' TVD 9-5/8" Shoe @ 2721' MD / 2469' TVD RUN TOTAL 40 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68 76 joints in the pipe shed. Run 70 joints - 6 joints stay out Use Best-o-Life 2000 i e do e MU torgue - 9000 ft/Ibs Remarks: Up Wt - 170k Dn Wt - 145k Block Wt - 75k Supervisor: D. Burley / D. Mickey `~ r .~~ Cement Detail Report CD3-111 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10103852 3!4/2006 3/6/2006 3/25/2006 -- - Cement Details _ - - Description Gementng Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/8/2006 00:00 3/8/2006 00:00 CD3-111 Comment Cement Stages --- - 1 Sta e;# 1 _ -- Description Objective -- Top (ftK6) Bottom (ftK6) Fuii Return? Cmnt Rtrn (... Top Plug? Btm Ptug? Surface Casing Cement Primary cement 36.0 2,721.0 Yes 106.0 Yes Yes Q (start) (bbllmin) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 6 610.0 1,100.0 Yes 20.00 No Depth tagged (ftK8) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment -- - - GemenfFlwds & Additives - - -__-- -- - __ ---- ___ ~~Fluid Fluid Type Fluid Description Estimated lop (ftK6) 'Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 2,221.0 410 G 325.4 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fiwd Descripbon Class Estimated Top (ftK6) Est Btm (ftK8) Amount ~ Volume Pumped (bbq Tail Cement ~> ~ 2,221.0 2,721.0 G 49.6 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plas 'c Visc sity cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 15.80 Additives Additive Type Concentration Conc Unit label Page 1/16 Report Printed: 12128/2006 r ~ ~ Security Level: Development I Daily Drilling Report ' r CD3-111 E, Report Number: 5 Rig: DOYON 19 Report Date: 3/8/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftKB) Depth Progress (ft) CD3-111 Development FIORD NECHELIK 3/6/2006 2.77 2,731.0 2,731.0 0.00 AFE I RFE I Maint# Daity Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10103852 6,134.53 48,028.60 441,102.53 929,918.60 5,411,831.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) 9 5!8" Surface Casing, 2,721.OftK6 Ops and Depth @ Morning Report 24hr Forecast RIH w/ BHA # 2 Drill 8 3/4 hole Last 24hr Summary Finish LD BHA - RU & run 9 5/8" csg to 2721' - Cmt csg - RD cmt i;< csg equip - RU & test BOPE General Remarks Weather Head Count -31 12 mph -57 WC 48.0 - ;,: ~• ~ ~ ~ s,. - - --- i - ~ ~n~ ~~ Dave Eurley .Rig Supervisor Do~~ Mickey Rig Supervisor Time Log Srart T irr ~... E,~~1 Dw l u 1 h'=_] i Fnase Op Cede ~(3pSuh-,o:. -~° Tine P-N I- T~bi :ode ~ T, bi Gasa I h Jt -~ rn II tK8 ~•F. ~) ~ .~ ~ Cor~~~JJr t:..ion 00:00 __ 00.45 0.75 SURFAC DRILL PULD P U.0 0.0 Lay down motor -clear tools from rig floor 00:45 02:30 1.75 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 5/8" casing 02:30 02:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Pre-Job safety and Opts meeting with crew 02:45 06:30 3.75 SURFAC CASING RNCS P 0.0 1,525.0 Make up ~ Thread lock 9 5/8" Silver bullet float shoe, 2 - jts 9 5/8", 40#, L-80 , BTC casing, 9 5/8" Ftoat collar, Circ and check float equip., RIH with 9 518" casing to 1525' (40 jts total) 06:30 07:00 0.50 SURFAC CASING CIRC P 1,525.0 1,525.0 Circ BU, mstage rate up from 3.5 bpm to 5.5 bpm @ 290 psi - PUW 150K SOW 118K -Full returns 07:00 08:30 1.50 SURFAC CASING RNCS P 1,525.0 2,721.0 Continue running 9 5/8" casing to 2,677' (Total 70 jts) - MU FMC GEN V casing hanger and landing jt. -Land casing with shoe @ 2721', FC @ 2,640' 08:30 09:15 0.75 SURFAC CEMENT PULD P 2,721.0 2,721.0 Lay down Frank's fill up tool -blow down top drive -Make up Dowell cement head 09:15 11:00 1.75 SURFAC CEMENT CIRC P 2,721.0 2,721.0 Stage pumps up to 7 bpm / 320 psi - circ and condition mud for cement job -Held PJSM with all personnel 11:00 13:00 2.00 SURFAC CEMENT DISP P 2,721.0 2,731.0 Pump 40 bbls biozan water w/ nut plug at rate of 6.0 bpm @ 190 psi with rig pump, Swith to Dowell & pump 5 bbls water, Test lines to 3000 psi, Drop btm plug, Mix & pump 50 bbls 10.5 ppg MudPUSN XL at rate of 6.0 bpm @ 540 psi, Mixed & pumped 325 bbis {410 sxs) 10.7 ppg Lead slurry plus additives at rate of 7.5 bpm @ 755 psi, Observed nut plug at shakers after pumping 310 bbls lead, Switched to Taff ~ pumped d9:6 bbls {230 sxs) plus additives at 15.8 ppg at rate of 6.1 bpm @ 880, Shut down & drop top plug, Displace plugs w/ 20 bbls fresh water, Switch to rig pumps & displace w/ total of 181.0 bbls 10.0 ppg mud at rate of 8.0 bpm @ 570 to 800 psi, Slowed rate down to 3.1 bpm @ 550 to 610 psi on last 6 bbls, Bumped plug w/ 1100 psi, C.I.P @ 12:53 hrs 3/08/06, Floats held. Had fuN retums thru out job w/ 106 bbls 10.7 ppg cmt returns to surface. Stopped reciprocating casing after pumping 25 bbls of mud displacement due to decrease in down weight. 13:00 14:00 1.00 SURFAC CEMENT PULD P 2,731.0 2,731.0 Blow down lines - RD cmt lines & head - LD landing jt. 14:00 15:30 1.50 SURFAC DRILL RURD P 2,731.0 2,731.0 ND surface riser 15:30 16:30 1.00 SURFAC DRILL OTHR P 2,731.0 2,731.0 Install FMC wellhead & test seals to 1000 psi 16:30 18:00 1.50 SURFAC WELCTL NUND P 2,731.0 2,731.0 NU BOPE Latest BOP Test Data ___ _- -- - -- -- Dace ..._ ----. 3/i3/2006 250 & 5000 si H dril 250 8 3500 Page 1/2 Report Printed: 12/28/2006 ~ ~ Security Level: Development Daily Drilling Report CD3-111 Report Number: 5 ~. . Rig: DOYON 19 e ort Date• 3 p - - -- ----- - - -- -- Time Log I sun E-,~ n,~~ ~ TimE Tirr ~ Time trr~1 li Pha<e l + ~o '_ ~ OpSu Co _~-N ~ 18:00 23:30 5.50 SURFAC WELCTL ROPE P -- - - --- - - -- ~, i=s~~~~ n urn E -. -- _ - ~ I - _--- Tr'~I ~~de ~ TiLI (.lass. iftKG' flH:F ~.c mwOp i anon - 2,131.0 2,131.0 RU & test BOPS - Hydrd to 250 & 3500 psi -pipe rams, blind rams ,choke & kill line valves, choke manifold , TD IBOP's, dart & floor safety valve to 250 & 5000 pis - Prformed accumulator closure test. witnessing of test waived by John Spualding AOGCC 23:30 00:00 0.50 SURFAC WELCTL BOPE P 2,731.0 2,731.0 Puli test plug -set wear bushing -blow down lines Mud Check Data - -- ~ -- ~ - - ~ Ty,~e C~_pth (hhf-1 Densib~aal~Vi~'s ql) PV Cac~ccgl spud mud 2761 0, 9 90 73~ 14-0 l I G 10m) ( I -C n) ~ Hl I If Fill Derr l mp ~hri Corr Pc~~ -~,_ino ~ ~ ~ ~~-~ ~ ~..~:,. ..~., -__ - ~ - F, (J.,f D;,t~ 3 QF111~C41~; 'i (t /1tY~t'j IL(1C' 1 FdHi t,G,"vl) ~ , 16.000 7 OOO 30 OOO 33.000 25.0 9-0 i 9.OI i I l - L - - - -- In action Fluid - -- - Fiu,a Scarce Diesel - CD3-111 - - - - -- - - - - -- 7 _- - - - - rime Rim lease (bbl) D=Ana'-ic^, I 15.0 CD3-109 Other CD3-111 530.0 CD3-109 Recycled mud CD3-111 Water CD3-111 -__ 1233.0 CD3-109 90.0 CD3-109 Weiibores WBlibore Name CD3 111 Wellbore APIIUWI ~ 501032052600 ---- - - ,S~~r,.,n I 5 _~ '.n1 GOND1 -- ---- ~ - 24' SURFAC 12 1/4 INTRMI 8 3/4 PROD1 6 1/8 - ~. End Daf _ Ad Top (ffKBJ ~ Act Btm {IiKB) Sian Date _ 0.0 - 114.0 2/15/2006 2/15/2006 - 114.0 2,731.0 3/6/2006 3/7/2006 2,731.0 8,670.0 3/9/2006 3/11/2006 8,670.0 15,073.0 3/14/2006 3/19/2006 - - Cement - - ~ -- - - - - Surface Casin Cement -Started 3/8/2006 Type Wellbore String Cement Evaluation Results casing CD3-111 9 5/8" Surface Casing, 2,721.OftKB Pressure tested to 2500 psi for 30 mins. Stg No. Description Top (ftKB) Bottom (ftK6) Q (end) (bbl/... P (£nal) (psi) 1 Surface Casing Cement 36 0 2,721.0 3 610.0 - 1:13 s.. Amount{sacks 1- d NOD`. .Den 'r ~;olgat) ~-u ~~fNlsack) Esi Top~RKB) ~ F3t"Btm (ft}CBj F i~~;~ 410 325.4 Lead Cement G _~___ 10.70 4.45 36.0 2,221.0 Tail Cement G 49.6 15.80 1.17 2,221.0 2,721.0 Page 2/2 Report Printed: 12128/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-111 Rig: Doyon 19 Date: 3/9/2006 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Burley / D. Mickey Pump used: #2 Mud Pump ~ strokes ~ 0.1000 Bbls/Strk ~ 0.8 Bbl/min ~ Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down annulus and DP. ~ Casin Test Pressure In te rit Test Hofe Size: 83/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 34.0 Ft 2,721 Ft-MD 2,469 Ft-TVD 2,751 Ft-MD 2,494 Ft-TVD Strks psi Min si Strks psi Min si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 2530 0 0 0 670 Casin Test Pressure Int e rit Test 2 90 1 2530 1 80 0.25 550 Mud Weight: 9.9 ppg Mud Weight: 9.7 ppg 4 240 2 2520 2 150 0.5 550 Mud 10 min Gel: 22.0 Lb/100 Ft2 Mud 10 min Gel: 22.0 Lb/100 Ft2 6 510 3 2510 3 260 1 540 Test Pressure: 2 500 psi Rotating Weight: 135,000 Lbs 8 740 4 2510 4 380 1.5 53 Rotating Weight: , 130 000 Lbs Blocks/Top Drive Weight: 74,000 Lbs 10 900 5 2500 5 490 2 5 Blocks/Top Drive Weight: , 74 000 Lbs Desired PIT EMW: 18.0 ppg 12 1070 6 2500 6 580 2.5 530 , Estimates for Test: 1.7 bbls Estimates for Test: 1072 si 0.7 bbls 14 1260 7 2490 7 640 3 525 ~ ~ 16 1440 8 2490 8 680 3.5 525 EMW =Leak-off Pressure + Mud Weight = 990 PIT 15 Second 18 1640 9 2480 9 720 4 520 + 9.65 0.052 x TVD 0.052 x 2 9 Shut-in Pressure, si 20 1850 10 2480 10 770 4.5 520 EMW at 2721 Ft-MD (2469 Ft-ND) = 17.4 550 22 2050 15 2470 11 820 5 520 Lost 60 psi durin g test held 24 2270 20 2470 12 870 5.5 515 sooo , 97.6 % of te st pre ssure. 26 2550 25 2470 13 910 6 510 30 2470 14 960 6.5 510 15 990 7 510 zsoo 16 870 7 5 510 . 8 510 zooo 8.5 5 ~ 9 500 ~ 9.5 500 N 1 soo - 10 5 w a 1000 _ ,~" - ~- 00 i 0 2 0 2 5 30 p 1 Barrels 2 3 0 5 S 1 hut-I O PI 0 1 n tim T P i 5 e, M t inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back ~~CASING TEST -L EAK-OFF TEST o n S S S S omments: • ConocoPhilli S Casing Detail 7" Casin_g Well: CD3-111 Date: 3/1 312 0 0 6 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.20 FMC Gen V Hanger 1.68 34.20 Jts 3 to 202 200 Jts 7" 26# L-80 BTCM Csg 8535.35 35.88 Weatherford Float Collar 1.24 8571.23 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.36 8572.47 Ray Oil Tools "Silver Bullet" Float Shoe 2.08 8657.83 8659.91 TD 8 3/4" Hole 8669.91 8-3/4" Hole TD @ 8670 ' MD / 6933 ' TVD 7" Shoe @ 8660 ' MD / 6932' TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 138,139,140 Straight blade centralizer one per jt on every other joint Starting @ # 142 to 200 Top Nechelik - 8570' MD 6925 ' TVD 225 joints in shed - 202 total jts. to run Last 23 jts. out Use Run & Seal i e do e Remarks: Up Wt - 275 k Dn Wt - 170k Block Wt - 75k Supervisor.• D. Burley / D. Mickey • __ __ Cement Detail Report CD3-111 ' ` ' Intermediate Casing Cement Primary Job Type Job Category AFE ! RFE Start Date 3/4/200 6 Spud Date 3/6/2006 End Date 3/25/2006 DRILLING ORIGINAL DRILLING 10103852 _ Cement'Detaiis' Description Gementin Stag Date Gemen6ng End Date -- - - Wellbore Name Intermediate Casing Cement 3/13/2006 00:00 3/13/2006 15:45 CD3-117 Comment Cemen 9 - - -- -- __ -_ - -- - _ - Stage #. ~ _ - Description -- Objective - -- -- -- -- ~ Cmnt Rtrn (... Top Piu ~ 8tm Plu ~ - - -Bottom (fU(B) Fuli Retum. 9• Top (ftK6) Intermediate Casing Primary Cementing 7,729.0 8,660.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) O (end) (bbl/min) Q (avg ) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 4 520.0 Yes No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment -- _- - - - Cement Fluids 8 Additives - - - - - --- Fluid" Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) -- - - - - - _ - -- Glass Volume Pumped (bbl) 20 0 CW 100 Yield (ft'/sack) Mix H2O Ratio (gal/sa... 6,396.0 6,929.0 Free Water (%) Density (Iblgal) Plastic Viscosity (cp) . Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Type Concentration Conc Unit label Additive - Fluid Fluid Type -- _ _ Fluid Description -- _ - Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) - - -- Volume Pum ed bbf Glass P ( ) 30 0 MudPush Yield (ft'/sack) Mix H2O Ratio (gal/sa... 6,929.0 7,729.0 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) . Thickening Time (hrs) CmprStr 1 (psi) 12.50 Additives Type Concentration Conc Unit label Additive - - Fiuid- _ _ _ Fluid Type - - _ - - - Fluid Description --- -- - - Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) - - - -- - Volume Pum ed bbf Class P ( ) 2 39 Tail Cement Yield (ft'/sack) Mix H2O Ratio (gallsa... 7,729.0 8,660.0 190 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) . G Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Type Concentration Conc Unit label Additive Page 1/16 Report Printed: 12!28/2006 "'" Security Level: Deveiopmen>< Daily Drilling Report CD3-111 Report Number: 10 ~._ Report Date: 3/13/2006 Rig: DOYON 19 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftK6) Depth Progress (ft) 00 0 . CD3-111 Development FIORD NECHELIK 3/6/2006 7.77 8,670.0 8,670.0 Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount AFE I RFE / MainL# Daily Mud Cost 10103852 3,960.04 190,997.35 366,085.04 2,160,959.48 5,411,831.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) 7" Intermediate Casing, 8,660.OftK6 Ops and Depth @ Morning Report " 24hr Forecast Finish RIH -Test csg - C/O shoe Track -FIT -Drill 6 1 /8" hole DP f/ pipe shed RIH w/ BHA #3 - PU 4 Last 24hr Summary Finsih running 7" csg -Circ - Cmt 7" csg -Set & test pack -off - MU BHA # 3 Head Count General Remarks Weather -20 / - 50 WC / NE@.16 mph 46.0 Dave Burley Rig Supervisor (DOn Mickey Rig Supervisor - Time Lo - - - - - - _ -- 9 - ~ - - - - - ~ - - ii~ l ~ ECd o-~' Tur ~ ~.. Q'f tG SHrt ~ D-L`i F .d T r~rt~ or~_o n.-__[',~.- CI.-Rrh r;o ~P-tJ T~ 7rbl (~nae ~ Tt~~3ss i1tK8) (iLF..C'~ ~ Ccr~rrdt~pefaflu~ -r.. r ,,.~ - -- _. -_ - - - - OO:UO 01:00 1.OOI _ y NTRMI - - - CASING - - RNCS __ P ( un - 63 jts total) 101:00 01:30 0.50 I NTRMI CASING CIRC P 2,699.0 2,699.0 Circ and condition mud - 5 bpm / 320 PSI PUW 150K SOW 120K 01:30 03:45 2.25 I NTRMI CASING RNCS P 2,699.0 5,295.0 Run 7" casing from 2,699' to 5,295' - (124 jts total) i 03:45 04:30 0.75 INTRM1 CASING CIRC P 5,295.0 5,295.0 Staged pumps up to 5 bpm ICP 730 psi -FCP 450 ps PUW 185K SOW 155K 04:30 07:15 2.75 INTRM1 CASING RNCS P 5,295.0 7,740.0 Run casing from 5,295' to 7,740', unable to work past tight spot at 7,740' 7 683 0 attempted to circ -pipe packed off. 725' to 7 ked u Pi 07:15 08:00 08:00 09:00 0.75 1.00 INTRMI INTRMI CASING CASING OTHR CIRC T P Hole Conditions Underga... Ho. 7,740.0 7,683.0 , . 7,683.0 , , p c Lay down one joint of casing and pull up to 7683'. Establish circulation -staged pumps up to 4.7 bpm !440 psi -circ and condition mud 09:00 10:15 1.25 INTRMI CASING CIRC T Hole Conditions Underga... Ho. 7,683.0 7,769.0 50pstl~worked/through ght6spotfrom7,702't b7710' -cleaned up after several passes. 10:15 11:45 1.50 INTRM1 CASING RNCS P 7,769.0 8,660.0 Continue running 7" 26# L-80 BTCM csg f/ 7,769' to 8,624' (202 jts total ran) PU FMC fluted hanger ii< landing jt. -land casing in wellhead w/ shoe @ 8,660' & FC @ 8,571' - String wt. Up 275 K Down 170 K 11:45 12:15 12:15 14:15 0.50 2.00 INTRMI INTRMI CASING CEMENT RURD CIRC P P 8,660.0 8,660.0 8,660.0 8,660.0 LD fill up tool -Blow down TD - RU cement head 8~ lines Establish circulation @ 2.0 bbls/min @440 psi -Stage pumps up to 5 bbls/min @ 520 psi -Circulate & condition for cement job -FCP - 450 psi @ 5 bbls/min Had full returns while circulating PJSM w/ Dowell and crew 14:15 15:45 1.50 INTRMI CEMENT DISP P 8,660.0 8,660.0 Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to 4000 psi -pump 15 bbls CW-100 @ 4.1 BPM @ 450 psi -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4.4 BPM @ 525 psi -Drop btm plug -Mix & pump 39.2 bbls (190 sxs) Tail slurry (Class G w/ .2% D046, .3% D065, .07% B755, .4% D167) @ 15.8 ppg - 4.5 BPM @ 700 psi - Drop top plug -Pumped 20 bbls water w/ Dowell - Switch to rig pumps 8~ displaced w/ 311 bbls 9.8 ppg mud @ 6 - 7 BPM @ 190 to 540 psi -slowed rate to 3.5 BPM for last 10.0 bbls -540 psi final -did not bump plug - check floats - OK - CIP @ 15:45 hrs. Full returns throughout job, Worked casing 20' until last 23 bbls of displacement Latest BOP Test Data - - -- - -~- ~ --- C ~mmene -- - - ...- --_. _ -- Date ~_ 3/8/2006 250 i£ 5000 si H dril 250 & 3500 Page 1/3 Report Printed: 12128/2006 5ecurlry t_evel: Uev6wNmCn~ Daily Drilling Report CD3-111 Report Number: 10 ' • .• ,s Report Date: 311 312 0 0 6 Rig: DOYON 19 - -_- - - -- - Tlme Log- _- - _ D~~a Dur~ i ~ ~i Time Sta-1 _- - - - - ~ D P[h brat/ ~ qtr; Bid ~ - - -- - -- --- - ~ ~: ~3t~~~ ~~m~,,io ~ rim nm~ ~ n~=; I ~h~« ~ u~ cow c~~sue co_ F-N r r.t~, c~+r -_r T ~ _ e ~i~ss nee; ,r,N:~~ ~ - -- - - -- 0 RD ctm lines & head - LD landing fit. - LD csg elevators 660 0 8 660 8 RURD P 16:45 1.00 INTRM1 CEMENT 15:45 . , . , . 8~ slips 0 Pull thin wall w 0 0 0 ear bushing -Set & test 7" pack-off to 16:45 17:30 0.75 INTRMI DRILL OTHR P . . 5000 psi 0 Set test plug - 0 0 0 change top pipe rams to 3 1/2" x 6" VBR - 17:30 19:45 2.25 INTRM1 WELCTL EORP P . . Test to 5000 psi -Function lower pipe rams & Hydril - Pull test plug 19:45 20:15 0.50 INTRM1 DRILL OTHR P 0.0 0.0 Set wear bushing 0 PU drilling bails & DP elevators 0 0 0 20:15 21:00 0.75 INTRMI DRILL PULD P . . 0 MU BHA #3 - 0 116 0 bit, GeoPilot, MWD componets - Up load 21:00 00:00 3.00 INTRMI DRILL PULD P . . MWD .Mud Check Data _ - I -- -- YP Ca ~ I ~~ ~ -- - - ~ 1 ~ V i ~~m, I ( ~~ I3 i ~i ~- H ~ ~ -' o -- rr ~ i~ -, car I HP 1'dt - - F ~ ~ 6~ "" i I ~~f110!~t Ibt i~E ~ Depth (fth8~ liens i~.,,ya~) ~ . y.~ ~ ~1~ C~_.;_p) Water 8,670.0 9.80 , ~37 9.0 17.000 Based Mud i Irt 10.,'tP) 11t f110,~7 ~ r.1BT ~IG.bbl) ~~yt"j 8.000 12.000 13.000 15.0 I ~L ~minl pFl - - - _ - _ 7.1 9.1 9.5 -I - - - I - - L - - -- In'ection Fiuid - - -- - - _ Flw,~ -_ ~u~cP ~- -~ - ' F - - - I, ... ~ ~:..5~ ;bb.j C' ~ ratio ~OoO OICD1-19 - - - rd ~~_ - --- -- - - - - ~ _ -_ _ - 3-111 Water Based Mud 1, D -I _ - Dnll Strnn s: BHA No_ 3 - 6 118 BHA #3'/ Bit Run No 3 - 6 1l8in, Securi DBS,`~SF 2553, 10751523 _ - - -- -- iADC Bit Dull ~ String Wt (10001bf) WOB (max) (100... WOB (min) (1000... " s ) ) Nozzles (132 Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in NO-A-X-O-NO-DTF 9 0 0 12 0 8,670.0 10,657.0 0.45 14/14/14 - - Drill Strin Com_ ponents -- - - - - fi n - ~ - -- -- - - u -- ~ - - ,_ - - - OD n, ~ ID iloj-~ ToF r - - - ~ - - - c.:~m ten (ft)'' ~~ Sz l 4 j lop Thread' - - - - em {}es o tp l: _ _ _ _ -_ ~_ - - - - Jts - - - - - -- 4 3/4 1.500 17 38 3 1/2 NC 38 1 Geo Pllot 4 3/4 1.500 3 1/2 NC 38 28.92 1 Drill Collar -Flex Non Mag 76 1.500 4 32.51 3 1/2 NC 38 1 Stabilizer (Non Mag) . 4 3/4 1.500 3 1/2 NC 38 41.0E 1 MWD DM HOC 73 1.500 4 3 1/2 NC 38 64.8 1 MWD GR/RES . 74 1.500 4 3 1/2 NC 38 90.2E 1 MWD DENSITY . 7 1.500 4 3 112 NC 38 101.11 1 MWD (Dir & Logging) . 62 1.500 4 111.11 3 1/2 NC 38 1 MWD TM HOC . 66 2.313 4 3 1/2 NC 38 113.5 1 Float Sub . 4 3/4 2.250 3 1!2 NC 38 119.0; 1 Stabilizer (Non Mag) 64 2.250 4 150.0: 3 1/2 NC 38 1 NMDC . 4.52 2.250 3 1/2 NC 38 180.9! 1 NMDC 54 2.250 4 3 1/2 NC 38 212.0; 1 NMDC . 4 3/4 2.563 4 XT 39 214.61 1 XO Sub 4 2.563 4 XT 39 306.61 3 HWDP 4 3/4 2.000 4 XT 39 339.1 1 Drilling Jars -Mechanical 4 2.563 - -400.51 4 XT 39 2 HWDP , - - - - - - DnllingParameters - ShJi Hrs 1 --- ~ ~ (urn DnI -- 7 RF,r~ - - 1. rfloe~ r~uti~ r~~nlt~ ~ oN~ 1~6~'Ihfj f 0C~ ~ O't Btrn Tq Dnli Tq (fl hB' ~ I-i r'fti S rt tthBl ~ En ~ ,Cum Depth {f t~ ~ Time fhr) ~ SI-'F t -it.~ l9Pm ~ 1,NOB;iv 1 ,rprn) P j ~ r1 lt rt:rJUlbi) - --L - --._ - _-_. ~ _ - -- - ~ -- ~ 614.4 8,6 ~ 0 0 8 - , - - Wellbores - - - Wellbore APUUWI - --- _- Wellbore Name 501032052600 - - --~ - 11 .CD3 1 ~ _ ~ (flKBI -- Act Litm {ftK ,qct iop B) - -- S.a ~ Da ~ -... - -- ~ -- -- -.. -.- . - _ - Er j D atP - --- - -- c'¢m _ - - i-e - - - - 24 - . - - - - 0.0 --- 114.0 2/15/2006 2/15/2006 COND1 12 1/4 114.0 2,731.0 3/6/2006 3/7/2006 SURFAC 8 3!4 731.0 2 8,670.0 3/9!2006 3/11/2006 INTRMI 61/8 , 670.0 8 15,073.0 3/14/2006 3/19/2006 - PROD1 _ -- , , - -_ _---- _ ,Cement -- - - - - --- - - -- Intermediate Casing Cement -Started 3!13/2006 re...enF Fveh.~finn Rasulfs casing /CD3-111 I7" Intermediate Casing, 8,660.OftKB Page 213 Report Printed: 12/2812006 Security Level: Development 100 Push Cement tig: DOYON 19 Description Intermediate Casing Cement Fluid - -r ~~.I~rs Daily Drilling Report CD3-111 190 7,729.0 ~ 8,660.0 TDensi~ il, csli- -i'~eld{fl'/saG, 20.0 8.40 30.0 12.501 39.2 15.80 1.16 Page 3/3 Report Number: 10 Report Date: 3/13/2006 id) (bbl/... IP (final) (Psi) - 4 520:0 <s~~ [ st Btm n+ce~ _ 6,396.0 6,929.0 6,929.0 7,729.0 7,729.0 8,660.0 Report Printed: 12/28120061 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. JVell Name: CD3-111 Rig: Doyon 19 Date: 3/14/2006 Volume Input Pum Rate: Drilling Supervisor: Mickey /Burley Pump used: Cement Unit ~ Barrels ~ Bbls/Strk ~ 0.80 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 36.1 Ft 2721.0 Ft-MD 2469.0 Ft-TVD 7729.0 Ft-MD 6552.0 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Description: 9-5/a" 4o#/Ft L-8o aTC ~ 0 0 0.00 450 Chan es for Annular Ade uac Test Pressure Int e rit Tes t 1 0.5 130 0.25 424 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 261 0.50 421 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 342 1.00 415 Hole Size is that drilled below outer casing. 4 2 409 1.50 412 Use estimated TOC for Hole Depth. 5 2.5 523 2.00 40 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 592 2.50 406 Estimates for Test: 668 psi 0.5 bbls 7 3.5 615 3.00 404 ~ ~ 8 4 567 3.50 401 EMW =Leak-off Pressure + Mud Weight = 615 PIT 15 Second 9 4.5 516 4.00 401 + 9 0.052 x TVD 0.052 x 2469 ~ Shut-in Pressure, si 10 5 494 4.50 398 EMW at 2721 Ft-MD (2469 Ft-ND) = 14.6 424 15 5.5 511 5.00 397 20 6 489 5.50 395 loo0 25 6.5 505 6.00 391 30 6.50 387 7.00 384 7.50 385 00 8 382 . w 8.50 380 ~ 9.00 382 9.50 379 w soo 10.00 377 a .~., q "~."'-" o ~ 2 0 2 5 30 0 ~~C 1 ASING TE 2 Ba ST 3 rrels 4 --F LEAK 5 -OFF TES 6 T 7 0 5 10 1 Shut-In tim O PIT Poi 5 e, M nt inute s Volume Pum ed _ Volume Bled Back Vo Pu lume m ed ~ Vo Bled lume Back a 5izs_. snoe w i cu _i i 4 ppg Summary `1`t1:tt and Shannon , Xou haue r~c~~sted to dispr~~e of "rre~Y-pr~iducC" ~le~rn rip fluids 'from the routine mixing cf mid azld cemen4 atr.liZar.e~ as *aell as tha clea.-~ up fluids resulting E ~ OI71 clc~aninq our. the tan;es at the mud. planC in pra_raration for using oil base a~ud. TJ~~ Cca.:snissic:7 had pxe-~.trus~.y ~3pp="ovcrl dzsposinq of the 'nev: ~rad.uct" cl~~r~ up l~.! iris via. ar_nular disposal at CLr i pad. I~u~. to the geUlot~ical seLCinc: at alpine, ~C1ass t and:. Class 2 d~osa3 gpCiat~s -are lir,^,ited. Phllzps` precccessar, ~~~'Cl, 1!a~ estrbwi~}'red khe lim.tati.nn of risposal options. to Ct'ie Cdr„missian`'s satisfa~cr.ion ~rrl anr_vlar digpvs~l wa4 eppr`~~ed as tt7e t>Yact~-~a1 and en~rironmental aLter'nat~~ac~. In these requests tyre wasCe fluids axe r'1o dz~~e~'crt than previously ,a~F~'oved ar.d ~sre the rr~sult o` the. ongoing tiet~elCapnteri activiries at :~lpirz~- The CamnGissit~ners have authar.izec3, me r.o send you this mc:~sage. By cofxy o h-s omGil; Phillips is auLYiora~zecl tC3 dispose of clean up fluids as described in Yu crr~il _ Please cell with :any gaestzcans - Sr. Petzraleutn Engineer ~~~~ ~a,13 Ez~v Cc~ord Yrrate: } near AIr. Maunder, > ~ noted i_r tt~a~ attac:aed erriaS.l. ~.`om Marxs~c~n ~axevir,usly reque~~trd > auChorazar.ir~r~ to .dispose of new-product. clea_z up fluids: such as cement y rir_sate, and [nuc't and 'rir'ine pit, xinse5 fr~am mixing q:~crations iris annular > inlecCion r. pexsna_rtc'a wells ;at the Alpine CD2 gill rite.. ~~s r~a~,ed belac~, ~ I~CJC-~G' approtred such ~iisposal_ at the CD1 ~xill ait:e ~.rt 199, based. tin t~tc ~- integral rcl.atiQnshi~r cf tt~e mtrd mixirrA tacili *y a~td the can-site drilline~ :~ operat:ion. - Phillips` would lzke to c_~orzti.nul,ng pursuinct .his request. Signifidank: clears out of wanks ~.t themud mixing Facility must C>CCI.~Y in `prepaxation fo:." thg tcz€cporary use o£ oil based mud proaucts at Alpine ~;n the coming months= > The- availabiliCy of annular disposal ~~-~s an apt-icon for tank rirYSe flni.d acrd > similar vrastes ,could grc,atly facilitate this. process. (Typically, routine } ranse5 art beneficially reused, however, there is a concern about the > pa~ential cuanCity caf fluid Chat could. tae generated during this large scale cyan. up prcl~ess.3 ~ Tanks ar_ the nude s:xirrg facility .may cot1+-~.i~ e~..tner ~re~a and us+~d mud > products. 'Lhoug:~ rinses in contact `~rithused ptioduc~s zna~,I bo injectedsn ~ the permitted .class I I disposal atell (C~7 9~nt rimes of near. products would > r.~o:ent;ally be rot;~ec~ tQ the class ~ disnnsal ~rFell (6,~-{l2} , v.h~re Lhexe is ~ a c3.iffic'ulty nanar3ing solids cartent- Tare class I ~Xel;l i.s a critita3. y 1i£o7,nc f©r'faciiity nfrastruLtu~e, k~eing the disposal lacati.~n for'all a domestic effluent, and iL is a priority tti pxevetlt anv compromise to this dzsposal facility. annular disposal. presents a prefer~,ed vrast~ m~nagez~eriL. ~ alternati.re a.n thiscas~e- ~~ ~~~~ C 22} s- a > TI`han~c you ve_y niuc2 far your cazsciera~iUn of phis ~equc~sx. ~l~ase dc~ nit > Yresitate ~a cc~nCacr nse ~~ my alte~rrace -aia email ar ghonc: at f90?~ X70-42r3~ > if ys~u have c~sestic~r.s or neea ~itlda.~i:anal irsforuiatitss~. ,~,hanz~on ~s~nnell;~ > 3.l.pine ~ie?ci Envire~nm~nL-al Caordi>aa'Lo2 {977 67Q-42+Jq ~____ Ft~r*.vaxded by AL;P ~nv CcsardfFPCG ~z 11IG2~ti1 =2:~T7 PM ___.„,~ ALP En~r Ca~c~rd Ggf 3~ Ja? 1Z : 95 PN r To: Cn:~m~~txndert?admiri. ,.~te.a:c.us ,. C C Sulaject: R~;t~uL' Go I:x~jecY f'~n~ ~];1~Sc"~G~ at 2 > Dear I•ir. Maun<ie~', InjecCon ~f csm~nt rins~te and +~:t~an-un fluids from at~aci acid br:irse ntixinc~ `- operations aC f>re 7alpine mud plant. faciliCy int;c5 ar;proved annu7,ar elisposal vperaUions _t;as gzt~tlCed key Lire ~.l as'ra Oi 1, And has Conservat itsra Gozncnissiozi > tAt~GCC~ _n the March 1.J, 1999 letter ~iom AUGCC tU i7oucl Chester cif P.k~CO Alaska, =sc. , r<©~,~ L'hillips Alaska, Inc, (P'I) 'ihe approval -v;as granted to Pts? slaec3~ically fax Alpine L1ri? 1 Sirr~ CD1 arxd autisarizea vr~ltutieS up G~ 3,000 barrels Lhraagh the annular space. > PP,I request that this approval be extenc3eci to czri~.ling c~n~ratcns a~~ ~li'iir > I7s_11 Site GJ2. Cerner~t mixisr~r c~~~era~.w:?rs >c~r sitting surface conductors > v:zi l he raking places aY, r_he Gzind and Irjet faciliL-y s.~~sicr ~ rt~rr~ritly ~ a~~tacheo, to the drilling rica at ~:D~. t?gan r.o~~;~leCi.on of the cc~rnen+~inc~7 in > o~ the ca:~ductc~r.s~ t}~se lses ~snd mixing tan3c c.:ill have to be` xi.:rsed and Che= rinsa~~e clisposeci of. CAI request -approval Lc~ i_naert r_3~is rir.sc~C~, and ;- attier ~:Ieaa-tsp ~'ro-;: the rn=ad Ord brine mzxng ar~erations, into the anxual :- ~p~cc of apnro~ed :.fells located Gt Dr'13. Site CD2. ~ IL yc~u have an}r r~estions t~Icase contact me Wit- {>74-~20f~. TC~r1 Is2tI25~ri x ,~,1},n~ E`eld EuvLronm~nEal Ga::pliance torrtJn~under.vcf ORIGINAL ~ STATE OF ALASKA ~~iosioa OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim re~g~~3admin.state.a>i.us• acgcc ,prs.~d~oe b~:vowad:~in.stae.ak,~s 1301; eckenstsin~)admi:~.stat~:.ak.us Contractor: Doyon Rig No.: 19 DATE: 3/8/2006 Rig Rep.: Welsh/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Mickey Field/Unit & Well No.: Colville Rv CD3-111 PTD # 206-030 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign ~! Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. 'Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P TEST DATA Test Result P FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2850 P Pressure After Closure 1550 P 200 psi Attained 33 P Futl Pressure Attained 2 min 37 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2100 psi Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 28 Repair or rep-acement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim r~:~~~3admi:~.state.ak.us• Remarks: No Problems 24 HOUR NOTICE GIVEN YES X NO Date 03/08/06 Time Waived By John Spauldi 14:00 Witness Lupton/Mick~ Test start 18:00 Finish BOP Test (for rigs) BFL 11/09/04 Doyon19 3-09-06 CD3-111.x1s 'l~ '' ~~ ~' ,,~ ~ ,~~ ~ ~ ~ '°~~ ,' s'' ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~~~ ., ~~~~ ~~~~+r ~t~~ ~ ~~+ ~-7~~ O~ ~ ~ ~'t 333 W. 7`" AVENUE, SUITE 100 C01~5ERQATIOI~T CO1~Ir'II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, CD3-111 ConocoPhillips Alaska, Inc. Permit No: 206-030 Surface Location: 3945' FNL, 874' FEL, SEC. 5, T12N, RSE, UM Bottomhole Location: 3848' FNL, 4730' FEL, SEC. 30, T13N, RSE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the 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). Chairman DATED this ~3day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 20, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-111 Dear Sir or Madam: C~ ~OC1C3C0~11~~1 5 RECEIVED FER 2 1 2006 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Fiord CD3 drilling pad. The intended spud date for this well is 2/26/06 It is intended that Doyon Rig 19 be used to drill the well. CD3-111 will be an horizontal open hole producer in the Nechelik reservoir. At the end of the work program, the well will be closed in awaiting completion of well work and facilities construction that will allow the well to begin production fourth quarter 2006. A waiver for the diverter requirement is requested. This will be the 5th well on the Fiord pad and there has been no indication of gas or shallow gas hydrates. ~ 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 Liz Galiunas at 265-6247, or Chip Alvord at 265-6120. Sincerely, s Liz Galiunas Drilling Engineer • Attachments cc: CD3-111 Well File /Sharon Allsup Drake Chip Alvord Liz Galiunas Vern Johnson Jack Walker Jordan Wiess Lanston Chin ATO 1530 ATO 1700 ATO 1704 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation ~r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~n nnc ~~ nn~ 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil Q 1c. Specify if well is proposed for: ~ ~~~,~ Drill Q Redrill ^ Stratigraphic Test ^ Service ^ Development Gas ^ ~~ ~ Coalbed Methane ^ Gas Hy ra s ,, Reentry ^ Multiple Zone ^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: Blanket Q Single W II ^ 11. Well Name and Number. ConocoPhillips Alaska Inc. Bond No. 59-52- j 2"u ~` ~` CD3-111 ' 3. Address: 6. Proposed Depth: 12. Field/P/pol(s): ~ ~ 4 ~ P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16555 ~ ND: 6891 . IV@~~Jnlt 1. • ~ " ' ` 4a. Location of Well (Governmental Section): 7. Property Designation: ~ Fiord Nechelik Pool Surface: 3945' FNL, 874' FEL, Sec 5, T12N, R5E, UM ~ ?C' ADL 372105, 364471 .3~'~ Top of Productive Horizon: 8. Land Use Permit: ~Z. ~ 13. Approximate Spud Date: 4705' FNL, 442' FEL Sec 31, T13N, R5E, UM ~ LAS21122 2/26/2006 Total Depth: 9. Acres in Property: 14. Distance to Nearest .~-~~ ~Go.~y, 3848' FNL, 4730' FEL Sec 30, T13N, R5E, UM / .3~ ~' roperty: ,'4330 'CRU boundary zz c : 4b. Location of Well (State Base Plane Coordinate ~ ~ t L ~• ~ #,rt ~ ~ 10. KB Elevation L 7 f t 15. Distance to Nearest Well b• l CD3 110 2067 t 10400' W hi P . . ~ Zone- 4 Surface: x- 388169 ' y- '~ ): 36. ee (Height above G : - it n oo a 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ~jy~ ~ Maximum Hole Angle: 90.6 degrees ~~~ Downhole: 3179 ~ Surface: - 18. Casing Program: Specifications To p -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (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" T' 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 1t. ~ ~~ ~ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee 0 BOP Sketch ^ Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis^ Property Plat ^ Diverter Sketcl^ Seabed Report ^ Drilling Fluid Program ^~ 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date 2/20/2006 22. 1 hereby certify that the foregoing is true and correct. Contact L. Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature ~ a Phone 265-6120 Date 2/20/2006 Commission Use Only Permit to Drill ~~~/ '~~ ~~ API Number. `~~~ ~ ~~ ~~' ~ Permit Approval See cover letter for other , Number: Lam.-3(c.% 50- Date: requirements. val : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in sha~•~ Conditions of appr o Other. !.~ a3s <tilCal Samples req'd: Yes^ No ®" Mud log req'd: Ye~ No[]~ ~~- ~~~~C~ '~ ~A~a~ `vErT , ,J HZS measures: Yes^ No [v]` Directional svy req'd: Ye~ No ^ ~~~ ~S~ ~ie~\Y`cv~~~Y ~S~-, ~, APPROVED BY THE COMMISSION /~ ~ ~ ~ ~ - ,COMMISSIONER DATE: v vv-`-- RE~~IVED ~~~ F~~ ~ r Zoos ~` _ . ~[I>aska Oil ~ >~ .'.sign ..~ ~,~ ~i~' Form 10-401 Revised 12/2005 >/ Submit in Duplicate a~t~~~~~ • • CD3-111 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c finder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole /_7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low 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, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 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 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: CD3-109 Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 12-'/" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 9-5/8" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 8-3/4" drilling BHA. 9. Drill 8-3/4" hole to intermediate casing point in the Nechelik reservoir sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. BOPE test to 5000 psi. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and pull out of hole. 14. Run 3-'/2, 9.3#, L-80 EUE Mod tubing with TRM4E SSSV, gas lift mandrels, sliding sleeve, packer XN nipple, and wireline entry guide. Land hanger. 15. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17. Circulate tubing to diesel and install freeze protection in the annulus. 18. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 19. Set BPV and secure well. Move rig off. ORIGINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-109 is the nearest to the CD3-111 plan at 41' well to well separation at 424' MD. CD3-110 well to well separation is 21' at 323' MD. Drilling 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. Annular Pumping Operations: Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-111 will be injected into the permitted annulus CD3-109 or the class 2 disposal well on CD1 pad. "'~ The CD3-111 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The only significant hydrocarbon zones are the Nechelik and Kuparuk reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk as per regulations. Upon completion of CD3-111 form 10-403, Application for Sundry Operations -Annular Disposal, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL r • CD3-109 DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 %<" Intermediate hole to 7" casing point - 8 '/" Production Hole Section - 6 1 /8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5-9.0 9.0-10.0 9.0-9.5 PH 6 KCL Surface Hole: J A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. 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. ~~~r~~ ,,~. • • Fiord (CD3) Colville River Field CD3-111 Production Well Completion Plan 16" Conductor to 114' 9-5/8" 36 ppf L-80 BTC-Mod Surface Casing @ 2750' MD / 2500' TVD cemented to surface Packer Fluid mix: 9.2 ppa KCI Brine with 2000' TVD diesel cap Updated 02/20106 Sperry Sun Directional Plan WP02 3-1/2" 9.3 ppf L-80 EUE M Completion INS Tye tubing run with Jet Lube Run`n'Seal pipe dope Tubing Hanger 32' 32' 4-'/~' 12.6#/ft IBT-Mod Tubing (2 jts) Crossover 3-'/2' 9.3 #/ft EUE-Mod Tubing Camco TRMAXX-5E SSSV (2.812" ID) 2145' 2000' 3-''/z' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 3839' 3400' 3-'/~' 9.3 #/ft EUE-Mod Tubing c~ Camco KBMG GLM (2.867" ID) 6501' 5600' 3-'/~' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 7915' 6668' 3 '/~' tubing joints (2) Baker 3-1/2" CMD sliding sleeve 7955' 6689' w/ 2.813" X Profile 3-'/i' tubing joints (2) Baker Premier Packer 8075' 6749' 3 '/z' tubing joints (2) HES "XN" (2.813" ID)-64° inc 8155' 6786' 3-1/2" 10' pup joint WEG 8165' 6786' G~ ~ Baker Premier Packer at +/- 8075' MD +/- 200 TVD above Nechelik TOC @ - 7759 MD 16577' ND Well TD at 500' abov Kuparuk C - `~' 16555' MD / s 6891' TVD To~Kuparuk 8259' D / 6829' TVD Top Nechelik at 14' MD / 6969' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9053' MD / 6981' TVD @ 90° OR161NAL • • CD3-111 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: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2750 / 2500 14.5 1131 1635 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 = [(FG x 0.052) - 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 ~ ORIGINAL • • Cementing Program: 9 5/8" Surface Casing run to 2750' MD / 2500' TVD. Cement from 2750' MD to 2250' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2250' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1263' MD). Lead slurry: (2250'-1270') X 0.3132 ft3/ft X 1.5 (50% excess) = 460.4 ft3 below permafrost 1270' X 0.3132 ft3/ft X 4 (300% excess) = 1591.1 ft3 above permafrost Total volume = 463.7 + 1582.3 = 2051 ft3 => 462 Sx @ 4.45 ft3/sk System: 462 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint. volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7759' MD / 6577' TVD Cement from 9053' MD to 7759+/-' MD (minimum 500' MD above top of Kuparuk C reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (9053' -7759') X 0.1503 ft3/ft X 1.4 (40% excess) = 272.3 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 272.3 + 17.2 = 289.5 ft3 => 250 Sx @ 1.16 ft3/sk System: 250 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B 155 retarder and 0.4% D 167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-111 Plan: CD3-111 P a ~ - '1 Proposal Report 20 February, 2006 ~, HALL~BU~TDN Sperry Dritti~g Services ORIGINAL ~~ .-' cm°mmon Melh°tl: Minimum curvaw~e ERasystem: FS~WS^ Colville Riper Linit y~ ^ ~OI I~V~t~It~~'. SEr ortSUr/sceT'EIII Uwnlcton c~ e o ~m AI the CD3 N• AraS+ca ; ea aee wamins ~~~: GeoCeUC Datum: NAO t927 (NAOCON CONUS( Plan CD3'111 Magnef¢ MaOel: BGGM2005 Plan: CD3-111 ti Fat.t.,aataFtroty __ ___. .. 37fx,,<FF.£•,u, 33~a RK[3~ Pienner, LMy.^,n ;9:a. d9.64ft tIIaYon +4 {'s6.3 !~ `3.3jj ('iD3-1 ~ 1 W p02. 4ttt-rry 6t•~Cnq $etvt¢fs pl:z^JiJnpjA°_e~'f~ o4438Z4.:F2 'r:astinry;se4P X 33°<65.1? ~~ v Rst G~3 ~~ _ \ - Target (Toe); 16554.66' MD, 6891.60' ND, 1431.91' FSL, 520.65' FWL, Sec30 - T13N - R05E 6-1/8"Open Hole 9000 -I_ _ _ _ ____ , c 0 0 0 M .... 1= O Z .~ O G7 7" Csg - 8 3/4" Hole 7" Csg Pt. - 574.57' FSL, 442.42' FEL, Sec 31 - T13N - R05E _ . _ _ _ _ _ _ Target (Heel); 9053.28' MD, 6981.60' TVD Start Dir. 3° DLS, -13.39° TFO, 7148.11' MD, 6134.35' TVD 9 5/8" Csg - 12 1/4" Hole I Start Sail 34.27° INC, 1770.75' MD, 1690.47' ND 9-5/8" Csg Pt; 2750.33' MD, 2500.00' ND ~~ Kick-off Point, 2.5° DLS, 0.00° TFO, 400.00' MD, 400.00'lVD- - _ _ _ `~ SHL, 1334.53 FSL, 874 3T FEL Sec.S T12N - R05E i -12000 -9000 -6000 -3000 0 3000 6000 West(-)/East(+) (3000 ft/in) SHL; 1334.53' FSL, 874.37' FEL, Sec.S - T12N - R05E 0 0~ - - Kick-off Point, 2.5° DLS, 0.00° TFO, 400.00' MD, 400.00' ND 10, ~ ;-Base~Pennafrost --- Z~.. 3~ _ _ Start Sail 34.27° INC, 1770.75' MD, 1690.47 TVD c-ao ' g 5/8" Cs 12 1/4" Hole c-ao ' 9-5/8" Csg Pt; 2750.33' MD, 2500.00' TVD ~ 3000 c_2o Start Dir. 3° DLS, -13.39° TFO, 7148.11' MD, 6134.35' ND ... ' K 3 K3 Basal ' ~- r ~ - _ K_2 3~:. ,'' 7.. Csg - 8 3/4" Hole Q ~ K-2 Basal ,' 7" Csg Pt. - 574.57 FSL, 442.42' FEL, Sec 31 - T13N - R05E ~ Atbian 97 •U Albian 96 Top HRZ ~ - - - ,' ~~ ~ 600~~......_._.-,-...__.,..,.....c--. Base HRZ._.._....._..._.....__. ..... _.._ __ , -' ~ 6-1/8" Open Hol CD3-111wp02 - - -Top Kuparuk D h~ O , c_ ~ ' i ~ ~ - ~ Top Kuparuk C ~ ,.. T - 1-- Top Nu;gSUt Target (Heel); 9053.28' MD, 6981.60' ND Base Nuigsut ~cu I Target (Toe); 16554.66' MD, 6891.60' TVD, 1431.91' FSL, 520.65' FWL, Sec30 - T13N - 9000 Top Nechellk , 3000 0 3000 6000 9000 12000 15000 Vertical Section. at 324.00° (3000 ft/in~ ORIGINAL • • ~.-~ Sperry Drilling Services f13UATQ1~l ~1ALt ~t)1"lU)~t1P~'11~~1~}S Planning Report-Geographic _ ~ ~ - ----~~~----~------ Alaska Starry L,lir`iEling Services Database: EDM 2003.11 Single User db Local Co-ordinate Reference: Well Plan: CD3-191 Company: C:onocoPhillips Alaska Inc..'. TVD Reference: Planned Doyoh 19 @ 4$'.60ft (Doyon 19 (36.3 + 13.3)} ', 'Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 +-13.3)) , Site: Alpine CD3 North Reference: True WeII: Plan: CD3-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-1'1:1 Design: CD3-111wp02 roject Colville River Unit,North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: CD3-111 Well Position +N!-S i +E!-W Position Uncertainty j 0.00 fr Northing: 6,003,828.92 ft 0.00 fr Easting: 388,169.17 fr 0.00 fr Wellhead Elevation: fr Latitude: Longitude: Ground Level: 70° 25' 09.865" N 150° 54' 39.717" W 13.30fr I Wellbore Plan: CD3-111 ~-Magnetics Model Name Sample Date Declination Dip Angle Field Strength i i BGGM2005 2/20/2006 23.51 80.72 57,532 I 1 Design - CD3-111wp02 - --- Audit Notes: ~ ', Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +F31-S +El-W Direction lft} (ftl (ftl (°) 00.30 fl 00 0.00 324.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (~} (°) (ft} (ft} (ft) (°1100ft) (°7100ft) (°1100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 1,770.75 34.27 336.16 1,690.47 363.90 -160.82 2.50 2.50 0.00 0.00 7,148.11 34.27 336.16 6,134.36 3,133.35 -1,384.78 0.00 0.00 0.00 0.00 9,053.28 90.69 324.94 6,981.60 4,520.63 -2,219.12 3.00 2.96 -0.59 -13.39 16,554.66 90.69 324.94 6,891.60 10,660.51 -6,527.77 0.00 0.00 0.00 0.00 2/20/2006 10:20:40AM Page 2 of 8 COMPASS 2003.11 Burld 50 °~°~~. Y Sperry Drilling Services HAt.1..IBCIi=+t"~'~iV COnc}~t~ Pt'tll~tp~ Planning Report -Geographic ~ ~~r~~ g ~~ ~e lvas~ ~~ ttn sr,rt s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-111 Company: GonocoPhillips Alaska Inc. ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3}} Project: Colville River Unit MD Reference: Planned Dayon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3}} Site: r".Ipine CD3 North Reference: 'True Well: Plan: CD3-111 Survey Calculation Method: ? Minimum Curvature Welibore: Plan: CD3-111 Design: CD 3-111wp02 - _ _ --- Planned Survey CD3-111vdpC2 MD Inclination Azimuth ND SSND +NIS (ft) (°1 (°1 (ft1 (ftl fft} 36.30 0.00 0.00 36.30 -13.30 0.00 SHL; 1334.53' FSL, 874.37' FEL, Sec.S - T12N - R05E 100.00 0.00 0.00 100.00 50.40 0.00 200.00 0.00 0.00 200.00 150.40 0.00 400.00 0.00 0.00 400.00 350.40 0.00 Kick-off Point, 2.5° D LS, 0.00° TFO, 400.00' MD, 400.00' ND 500.00 2.50 336.16 499.97 450.37 2.00 600.00 5.00 336.16 599.75 550.15 7.98 700.00 7.50 336.16 699.14 649.54 17.93 800.00 10.00 336.16 797.97 748.37 31.85 900.00 12.50 336.16 896.04 846.44 49.69 1,000.00 15.00 336.16 993.17 943.57 71.43 1,100.00 17.50 336.16 1,089.17 1,039.57 97.02 1,200.00 20.00 336.16 1,183.85 1,134.25 126.42 1,270.37 21.76 336.16 1,249.60 1,200.00 149.36 Base Permafrost 1,300.00 22.50 336.16 1,277.05 1,227.45 159.57 1,400.00 25.00 336.16 1,368.57 1,318.97 196.40 1,500.00 27.50 336.16 1,458.25 1,408.65 236.85 1,600.00 30.00 336.16 1,545.92 1,496.32 280.84 1,700.00 32.50 336.16 1,631.40 1,581.80 328.29 1,770.75 34.27 336.16 1,690.47 1,640.87 363.90 Start Saii 34.27° INC, 1770.75' MD, 1690.47' ND 1,800.00 34.27 336.16 1,714.65 1,665.05 378.96 1,900.00 34.27 336.16 1,797.29 1,747.69 430.46 2,000.00 34.27 336.16 1,879.93 1,830.33 481.96 2,100.00 34.27 336.16 1,962.57 1,912.97 533.47 2,200.00 34.27 336.16 2,045.21 1,995.61 584.97 2,300.00 34.27 336.16 2,127.85 2,078.25 636.47 2,400.00 34.27 336.16 2,210.49 2,160.89 687.97 2,500.00 34.27 336.16 2,293.13 2,243.53 739.47 2,556.23 34.27 336.16 2,339.60 2,290.00 768.43 C-40 2,600.00 34.27 336.16 2,375.77 2,326.17 790.98 2,700.00 34.27 336.16 2,458.41 2,408.81 842.48 2,749.84 34.27 336.16 2,499.60 2,450.00 868.15 C-30 2,750.33 34.27 336.16 2,500.00 2,450.40 868.40 9-5/8" Csg Pt; 2750.33' MD, 2500.00' TVD - 9 5/8" Csg -12 114" Hole 2,800.00 34.27 336.16 2,541.05 2,491.45 893.98 2,900.00 34.27 336.16 2,623.69 2,574.09 945.48 3,000.00 34.27 336.16 2,706.33 2,656.73 996.98 3,100.00 34.27 336.16 2,788.97 2,739.37 1,048.49 3,200.00 34.27 336.16 2,871.61 2,822.01 1,099.99 3,219.34 34.27 336.16 2,887.60 2,838.00 1,109.95 C-20 Map Map +~,_~y Northing Easting DLSEV Vert Section (ft} (ft} (ft) (°1100ft} (ftl 0.00 6,003,828.92 388,169.17 0.00 0.00 0.00 6,003,828.92 388,169.17 0.00 0.00 0.00 6,003,828.92 388,169.17 0.00 0.00 ' 0.00 6,003,828.92 388,169.17 0.00 0.00 -0.88 6,003,830.93 388,168.32 2.50 2.13 ~ -3.53 6,003,836.95 388,165.76 2.50 8.53 -7.93 6,003,846.97 388,161.51 2.50 19.17 -14.07 6,003,860.97 388,155.58 2.50 34.04 -21.96 6,003,878.93 388,147.96 2.50 53.11 I -31.57 6,003,900.81 388,138.68 2.50 76.34 j -42.88 6,003,926.56 388,127.75 2.50 103.69 -55.87 6,003,956.15 388,115.20 2.50 135.11 -66.01 6,003,979.24 388,105.41 2.50 159.63 j -70.52 6,003,989.51 388,101.05 2.50 170.54 -86.80 6,004,026.58 388,085.33 2.50 209.91 -104.68 6,004,067.29 388,068.06 2.50 253.14 -124.12 6,004,111.57 388,049.28 2.50 300.16 -145.09 6,004,159.32 388,029.03 2.50 350.87 -160.82 6,004,195.15 388,013.83 2.50 388.93 i -167.48 6,004,210.31 388,007.40 0.00 405.03 i -190.24 6,004,262.15 387,985.41 0.00 460.07 -213.00 6,004,313.98 387,963.43 0.00 515.12 -235.77 6,004,365.81 387,941.44 0.00 570.16 -258.53 6,004,417.64 387,919.46 0.00 625.21 -281.29 6,004,469.48 387,897.47 0.00 680.25 -304.05 6,004,521.31 387,875.49 0.00 735.30 ~, -326.81 6,004,573.14 387,853.50 0.00 790.34 -339.61 6,004,602.29 387,841.14 0.00 821.29 -349.57 6,004,624.98 387,831.52 0.00 845.39 -372.33 6,004,676.81 387,809.53 0.00 900.43 -383.68 6,004,702.64 387,798.57 0.00 927.87 -383.79 6,004,702.89 387,798.47 0.00 I 928.13 I -395.10 6,004,728.64 387,787.54 0.00 955.48 -417.86 6,004,780.47 387,765.56 0.00 1,010.52 -440.62 6,004,832.31 387,743.57 0.00 1,065.57 ~ -463.38 6,004,884.14 387,721.59 0.00 1,120.61 -486.14 6,004,935.97 387,699.60 0.00 1,175.66 ~ -490.54 6,004,946.00 387,695.35 0.00 1,186.30 ~ 2/20/2006 10:20:40AM Page 3 of 8 COMPASS 2003.11 Build 50 ~~~~ • • ~~ Sperry Drilling Services H,x~.ttt~ul~l'~'gN ~?i1Q~4p'~i~~t~S Planning Report -Geographic _--- ' ~~'~~~-~ ~-~- ' 8pe~my L7<ri~Itng Servta>ts IalasE~ Database: FDM 2003.11 Single User Db Local Co-ordinate Reference: Well .Plan: CD3-111 Company: ConocoPhillips°Alaska Inc: ND Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River Unit MD Reference: Planned Doyonl9 @ 49.60ft (Doyon 19 (36.3 + 13,3}) Site: Alpine CD3 North Reference: True WeII; Plan: CD3-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-111. design: C~3-111wp02 Planned Survey CD3 111wp02 Map Map MD Inclination Azimuth ND SSND +N1-S +E!-W Northing Easting DLSEV Vert Section (ft) (~) (~) Ift) (ftl fft) (ft) (ft) (ft1 (°1100ft) (ft) 3,300.00 34.27 336.16 2,954.25 2,904.65 1,151.49 -508.90 6,004,987.81 387,677.62 0.00 1,230.70 3,400.00 34.27 336.16 3,036.89 2,987.29 1,202.99 -531.66 6,005,039.64 387,655.63 0.00 1,285.75 3,500.00 34,27 336.16 3,119.54 3,069.94 1,254.49 -554.42 6,005,091.47 387,633.65 0.00 1,340.79 ~' 3,600.00 34.2T 336.16 3,202.18 3,152.58 1,306.00 -577.19 6,005,143.30 387,611.66 0.00 1,395.83 3,700.00 34,27 336.16 3,284.82 3,235.22 1,357.50 -599.95 6,005,195.14 387,589.68 0.00 1,450.88 3,800.00 34.27 336.16 3,367.46 3,317.86 1,409.00 -622.71 6,005,246.97 387,567.69 0.00 1,505.92 i ~ 3,900.00 34.27 336.16 3,450.10 .3,400.50 1,460.50 -645.47 6,005,298.80 387,545.71 0.00 1,560.97 ; 4,000.00 34.27 336.16 3,532.74 3,483.14 1,512.00 -668.23 6,005,350.63 387,523.72 0.00 1,616.01 i j 4,100.00 34.27 336.16 3,615.38 3,565.78 1,563.51 -690.99 6,005,402.47 387,501.73 0.00 1,671.06 4,200.00 34.27 336.16 3,698.02 3,648.42 1,615.01 -713.75 6,005,454.30 387,479.75 0.00 1,726.10 4,300.00 34.27 336.16 3,780.66 3,731.06 1,666.51 -736.52 6,005,506.13 387,457.76 0.00 1,781.15 4,400.00 34.27 336.16 3,863.30 3,813.70 1,718.01 -759.28 6,005,557.97 387,435.78 0.00 1,836.19 4,443.92 34.27 336.16 3,899.60 3,850.00 1,740.63 -769.27 6,005,580.73 387,426.12 0.00 1,860.37 K-3 i I 4,500.00 34.27 336.16 3;945.94 3,896.34 1,769.51 -782.04 6,005,609.80 387,413.79 0.00 1,891.24 4,600.00 34.27 336.16 4,028.58 3,978.98 1,821.02 -804.80 6,005,661.63 387,391.81 0.00 1,946.28 4,624.22 34.27 336.16 4,048.60 3,999.00 1,833.49 -810.31 6,005,674.19 387,386.48 0.00 1,959.62 K-3 Basal 4,661.74 34.27 336.16 4,079.60 4,030.00 1,852.81 -818.85 6,005,693.63 387,378.23 0.00 1,98027 K_y i 4,700.00 34.27 336.16 4,111.22 4,061.62 1,872.52 -827.56 6,005,713.46 387,369.82 0.00 2,001.33 f i 4,788.79 34.27 336.16 4,184.60 4,135.00 1,918.25 -847.77 6,005,759.49 387,350.30 0.00 2,050.20 K-2 Basai ~' 4,800.00 34.27 336.16 4,193.86 4,144.26 1,924.02 -850.32 6,005,765.30 387,347.84 0.00 2,056.37 4,900.00 34.27 336.16 4,276.50 4,226.90 1,975.52 -873.08 6,005,817.13 387,325.85 0.00 2,111.42 i 5,000.00 34.27 336.16 4,359.14 4,309.54 2,027.02 -895.85 6,005,868.96 387,303.87 0.00 2,166.46 I 5,100.00 34.27 336.16 4,441.78 4,392.18 2,078.53 -918.61 6,005,920.80 387,281.88 0.00 2,221.51 5,200.00 34.27 336.16 4,524.42 4,474.82 2,130.03 -941.37 6,005,972.63 387,259.90 0.00 2,276.55 5,300.00 34.27 336.16 4,607.07 4,557.47 2,181.53 -964.13 6,006,024.46 387,237.91 0.00 2,331.60 , 5,400.00 34.27 336.16 4,689.71 4,640.11 2,233.03 -986.89 6,006,076.29 387,215.92 0.00 2,386.64 5,500.00 34.27 336.16 4,772.35 4,722.75 2,284.54 -1,009.65 6,006,128.13 387,193.94 0.00 2,441.69 ~ 5,600.00 34.27 336.16 4,854.99 4,805.39 2,336.04 -1,032.41 6,006,179.96 387,171.95 0.00 2,496.73 5,700.00 34.27 336.16 4,937.63 4,888.03 2,387.54 -1,055.17 6,006,231.79 387,149.97 0.00 2,551.78 5,800.00 34.27 336.16 5,020.27 4,970.67 2,439.04 -1,077.94 6,006,283.63 387,127.98 0.00 2,606.82 5,900.00 34.27 336.16 5,102.91 5,053.31 2,490.54 -1,100.70 6,006,335.46 387,106.00 0.00 2,661.87 I 6,000.00 34.27 336.16 5,185.55 5,135.95 2,542.05 -1,123.46 6,006,387.29 387,084.01 0.00 2,716.91 6,100.00 34.27 336.16 5,268.19 5,218.59 2,593.55 -1,146.22 6,006,439.12 387,062.03 0.00 2,771.96 200.00 6 34.27 336.16 5,350.83 5,301.23 2,645.05 -1,168.98 6,006,490.96 387,040.04 0.00 2,827.00 , 'i 6,300.00 34.27 336.16 5,433.47 5,383.87 2,696.55 -1,191.74 6,006,542.79 387,018.06 0.00 2,882.04 6,400.00 34.27 336.16 5,516.11 5,466.51 2,748.05 -1,214.50 6,006,594.62 386,996.07 0.00 2,937.09 6,500.00 34.27 336.16 5,598.75 5,549.15 2,799.56 -1,237.27 6,006,646.45 386,974.09 0.00 2,992.13 6,600.00 34.27 336.16 5,681.39 5,631.79 2,851.06 -1,260.03 6,006,698.29 386,952.10 0.00 3,047.18 6,65228 34.27 336.16 5,724.60 5,675.00 2,877.98 -1,271.93 6,006,725.39 386,940.61 0.00 3,075.96 Albian 97 6,700.00 34.27 336.16 5,764.03 5,714.43 2,902.56 -1,282.79 6,006,750.12 386,930.11 0.00 3,10222 6,800.00 34.27 336.16 5,846.67 5,797.07 2,954.06 -1,305.55 6,006,801.95 386,908.13 0.00 3,157.27 ~ 6,900.00 i 34.27 336 16 5 929 31 5 879 71 3 005 56 -1 328.31 6 006 853.79 386,886.14 0.00 3,212.31 I 2/202006 10:20:40AM Page 4 of 8 COMPASS 2003. ? 1 Build 50 • ~r-' ~UC1t ~CfJPh1~~pS'' Sperry Drilling Services hi Pl R G i rt ~..~~~~~~~-~-©~ -- , ann ng eograp epo - c Alaska Sperry DritCing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-111 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3}} Project: Colville River Unit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-111 Survey Caiculation Method: Minimum Curvature Wellbore: Plan: CD3-111 Design: ' 'CD3-111wp02 Planned Survey CD3-111wp02 <,, Map Map MD Inclination Azimuth TVD SSND +N/-S +E1-W Northing Easting DLSEV Vert Section (ft) (°) (`) Ift) (ft) (ft) (~) {ft) (ft) (°I100ft) (ff) 6,972.95 34.27 336.16 5,989.60 5,940.00 3,043.13 -1,344.92 6,006,891.60 386,870.11 0.00 3,252.47 Albian 96 7,000.00 34.27 336.16 6,011.95 5,962.35 3,057.07 -1,351.07 6,006,905.62 386,864.16 0.00 3,267.36 7,100.00 34.27 336.16 6,094.60 6,045.00 3,108.57 -1,373.83 6,006,957.45 386,842.17 0.00 3,322.40 7,148.11 34.27 336.16 6,134.36 6,084.76 3,133.35 -1,384.78 6,006,982.39 386,831.60 0.00 3,348.89 Start Dir. 3° DLS, -13. 39° TFO, 71 48.11' MD, 6 134.35' TVD 7,200.00 35.78 335.54 6,176.84 6,127.24 3,160.52 -1,396.97 6,007,009.74 386,819.82 3.00 3,378.03 7,300.00 38.71 334.47 6,256.44 6,206.84 3,215.36 -1,422.56 6,007,064.96 386,795.06 3.00 3,437.44 7,400.00 41.65 333.53 6,332.83 6,283.23 3,273.34 -1,450.85 6,007,123.35 386,767.64 3.00 3,500.98 7,500.00 44.60 332.69 6,405.81 6,356.21 3,334.30 -1,481.78 6,007,184.75 386,737.63 3.00 3,568.47 7,600.00 47.55 331.94 6,475.18 6,425.58 3,398.06 -1,515.24 6,007,249.01 386,705.13 3.00 3,639.73 7,700.00 50.50 331.25 6,540.74 6,491.14 3,464.46 -1,551.16 6,007,315.93 386,670.21 3.00 3,714.56 7,713.99 50.92 331.16 6,549.60 6,500.00 3,473.95 -1,556.38 6,007,325.49 386,665.14 3.01 3,725.30 Top HRZ 7,800.00 53.46 330.62 6,602.33 6,552.73 3,533.31 -1,589.43 6,007,385.34 386,632.98 3.00 3,792.75 7,900.00 56.42 330.04 6,659.76 6,610.16 3,604.42 -1,629.96 6,007,457.04 386,593.53 3.00 3,874.10 7,978.04 58.74 329.61 6,701.60 6,652.00 3,661.37 -1,663.07 6,007,514.47 386,561.27 3.00 3,939.64 Base HRZ 8,000.00 59.39 329.49 6,712.89 6,663.29 3,677.60 -1,672.61 6,007,530.85 386,551.98 3.00 3,958.38 8,068.25 61.41 329.14 6,746.60 6,697.00 3,728.64 -1,702.90 6,007,582.33 386,522.46 3.00 4,017.47 K-1 8,100.00 62.35 328.98 6,761.56 6,711.96 3,752.65 -1,717.29 6,007,606.55 386,508.43 3.00 4,045.36 8,160.06 64.14 328.69 6,788.60 6,739.00 3,798.54 -1,745.05 6,007,652.85 386,481.36 3.00 4,098.80 Top Kuparuk D 8,200.00 65.32 328.49 6,805.65 6,756.05 3,829.36 -1,763.87 6,007,683.95 386,463.01 3.00 4,134.80 8,259.36 67.08 328.22 6,829.60 6,780.00 3,875.60 -1,792.37 6,007,730.60 386,435.21 3.00 4,188.95 Top Kuparuk C 8,272.31 67.47 328.16 6,834.60 6,785.00 3,885.74 -1,798.66 6,007,740.84 386,429.07 3.00 4,200.86 LCU -Top Nu igsut 8,300.00 68.29 328.03 6,845.03 6,795.43 3,907.52 -1,812.22 6,007,762.82 386,415.84 3.00 4,226.45 8,400.00 71.26 327.59 6,879.59 6,829.99 3,986.92 -1,862.21 6,007,842.95 386,367.05 3.00 4,320.07 8,445.17 72.60 327.39 6,893.60 6,844.00 4,023.14 -1,885.29 6,007,879.50 386,344.52 3.00 4,362.93 Base Nuiqsut 8,500.00 74.23 327.16 6,909.25 6,859.65 4,067.34 -1,913.70 6,007,924.13 386,316.78 3.00 4,415.39 8,600.00 77.21 326.74 6,933.91 6,884.31 4,148.56 -1,966.54 6,008,006.12 386,265.16 3.00 4,512.16 8,700.00 80.18 326.34 6,953.51 6,903.91 4,230.36 -2,020.61 6,008,088.71 386,212.33 3.00 4,610.12 8,800.00 83.15 325.94 6,968.00 6,918.40 4,312.51 -2,075.74 6,008,171.67 386,158.44 3.00 4,708.98 8,813.80 83.56 325.88 6,969.60 6,920.00 4,323.86 -2,083.42 6,008,183.14 386,150.93 3.01 4,722.68 Top Nechelik 8,900.00 86.13 325.54 6,977.34 6,927.74 4,394.78 -2,131.78 6,008,254.77 386,103.64 3.00 4,808.49 9,000.00 89.10 325.15 6,981.50 6,931.90 4,476.96 -2,188.59 6,008,337.78 386,048.08 3.00 4,908.36 9,053.28 90.69 324.94 6,981.60 6,932.00 4,520.63 -2,219.12 6,008,381.90 386,018.21 3.00 4,961.63 Target (Heel); 9053.28' MD, 6981. 60' TVD - 7" Csg Pt. - 574.57' FSL, 442 .42' FEL, Sec 31 - T13N - R05E - 7" Csg - 8 3/4" Hole -CD3-111wp02 9,100.00 90.69 324.94 6,981.04 6,931.44 4,558.87 -2,245.95 6,008,420.53 385,991.96 0.00 5,008.34 220/2006 10:20:40AM Page 5 of 8 COMPASS 2003.11 Build 50 ~~~~~~-L • ~, ~Qt'i~C} CC3~~'1 { ~ ~ 1 ~}S Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-111 Wellbore: Plan: CD3-111 Design: CD3-111wp02 • Sperry Drilling Services ~~~~~~~-k ~ Planning Report -Geographic - --- Sperry Drilling Services Local Co-ordinate Reference: Well Plan: 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 - -- Planned Survey CD3-111vrp02 Map .Map MD Inclination Azimuth ND SSND +N!-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) 1~) (ft) lftl ift) j~) (ft) (ft) (°i100ft) (ft) 9,200.00 90.69 324.94 6,979.84 6,930.24 4,640.72 -2,303.39 6,008,503.23 385,935.75 0.00 5,108.32 9,300.00 90.69 324.94 6,978.64 6,929.04 4,722.57 -2,360.83 6,008,585.92 385,879.55 0.00 5,208.30 9,400.00 90.69 324.94 6,977.44 6,927.84 4,804.42 -2,418.26 6,008,668.61 385,823.35 0.00 5,308.28 9,500.00 90.69 324.94 6,976.24 6,926.64 4,886.27 -2,475.70 6,008,751.31 385,767.15 0.00 5,408.26 9,600.00 90.69 324.94 6,975.04 6,925.44 4,968.12 -2,533.14 6,008,834.00 385,710.95 0.00 5,508.24 9,700.00 90.69 324.94 6,973.84 6,924.24 5,049.97 -2,590.58 6,008,916.70 385,654.75 .0.00 5,608.22 9,800.00 90.69 324.94 6,972.64 6,923.04 5,131.82 -2,648.02 6,008,999.39 385,598.55 0.00 5,708.19 9,900.00 90.69 324.94 6,971.44 6,921.84 5,213.67 -2,705.45 6,009,082.08 385,542.35 0.00 5,808.17 10,000.00 90.69 324.94 6,970.24 6,920.64 5,295.52 -2,762.89 6,009,164.78 385,486.15 0.00 5,908.15 10,100.00 90.69 324.94 6,969.04 6,919.44 5,377.37 -2,820.33 6,009,247.47 385,429.95 0.00 6,008.13 10,200.00 90.69 324.94 6,967.84 6,918.24 5,459.22 -2,877.77 6,009,330.17 385,373.75 0.00 6,108.11 10,300.00 90.69 324.94 6,966.64 6,917.04 5,541.07 -2,935.21 6,009,412.86 385,317.55 0.00 6,208.09 10,400.00 90.69 324.94 6,965.44 6,915.84 5,622.92 -2,992.65 6,009,495.55 385,261.35 0.00 6,308.07 10,500.00 90.69 324.94 6,964.24 6,914.64 5,704.77 -3,050.08 6,009,578.25 385,205.15 0.00 6,408.05 10,600.00 90.69 324.94 6,963.04 6,913.44 5,786.62 -3,107.52 6,009,660.94 385,148.94 0.00 6,508.03 10,700.00 90.69 324.94 6,961.84 6,912.24 5,868.47 -3,164.96 6,009,743.64 385,092.74 0.00 6,608.01 10,800.00 90.69 324.94 6,960.64 6,911.04 5,950.32 -3,222.40 6,009,826.33 385,036.54 0.00 6,707.99 10,900.00 90.69 324.94 6,959.44 6,909.84 6,032.17 -3,279.84 6,009,909.03 384,980.34 0.00 6,807.97 11,000.00 90.69 324.94 6,958.24 6,908.64 6,114.02 -3,337.27 6,009,991.72 384,924.14 0.00 6,907.95 11,100.00 90.69 324.94 6,957.04 6,907.44 6,195.87 -3,394.71 6,010,074.41 384,867.94 0.00 7,007.93 11,200.00 90.69 324.94 6,955.84 6,906.24 6,277.72 -3,452.15 6,010,157.11 384,811.74 0.00 7,107.91 11,300.00 90.69 324.94 6,954.64 6,905.04 6,359.57 -3,509.59 6,010,239.80 384,755.54 0.00 7,207.88 11,400.00 90.69 324.94 6,953.44 6,903.84 6,441.42 -3,567.03 6,010,322.50 384,699.34 0.00 7,307.86 11,500.00 90.69 324.94 6,952.24 6,902.64 6,523.27 -3,624.47 6,010,405.19 384,643.14 0.00 7,407.84 11,600.00 90.69 324.94 6,951.05 6,901.45 6,605.12 -3,681.90 6,010,487.88 384,586.94 0.00 7,507.82 11,700.00 90.69 324.94 6,949.85 6,900.25 6,686.97 -3,739.34 6,010,570.58 384,530.74 0.00 7,607.80 11,800.00 90.69 324.94 6,948.65 6,899.05 6,768.82 -3,796.78 6,010,653.27 384,474.54 0.00 7,707.78 11,900.00 90.69 324.94 6,947.45 6,897.85 6,850.67 -3,854.22 6,010,735.97 384,418.33 0.00 7,807.76 12,000.00 90.69 324.94 6,946.25 6,896.65 6,932.52 -3,911.66 6,010,818.66 384,362.13 0.00 7,907.74 12,100.00 90.69 324.94 6,945.05 6,895.45 7,014.37 -3,969.09 6,010,901.36 384,305.93 0.00 8,007.72 12,200.00 90.69 324.94 6,943.85 6,894.25 7,096.22 -4,026.53 6,010,984.05 384,249.73 0.00 8,107.70 12,300.00 90.69 324.94 6,942.65 6,893.05 7,178.07 -4,083.97 6,011,066.74 384,193.53 0.00 8,207.68 12,400.00 90.69 324.94 6,941.45 6,891.85 7,259.92 -4,141.41 6,011,149.44 384,137.33 0.00 8,307.66 12,500.00 90.69 324.94 6,940.25 6,890.65 7,341.77 -4,198.85 6,011,232.13 384,081.13 0.00 8,407.64 12,600.00 90.69 324.94 6,939.05 6,889.45 7,423.62 -4,256.29 6,011,314.83 384,024.93 0.00 8,507.62 12,700.00 90.69 324.94 6,937.85 6,888.25 7,505.47 -4,313.72 6,011,397.52 383,968.73 0.00 8,607.60 12,800.00 90.69 324.94 6,936.65 6,887.05 7,587.32 x,371.16 6,011,480.21 383,912.53 0.00 8,707.57 12,900.00 90.69 324.94 6,935.45 6,885.85 7,669.17 -4,428.60 6,011,562.91 383,856.33 0.00 8,807.55 13,000.00 90.69 324.94 6,934.25 6,884.65 7,751.02 -4,486.04 6,011,645.60 383,800.13 0.00 8,907.53 13,100.00 90.69 324.94 6,933.05 6,883.45 7,832.87 -4,543.48 6,011,728.30 383,743.93 0.00 9,007.51 13,200.00 90.69 324.94 6,931.85 6,882.25 7,914.72 -4,600.92 6,011,810.99 383,687.72 0.00 9,107.49 13,300.00 90.69 324.94 6,930.65 6,881.05 7,996.57 -4,658.35 6,011,893.69 383,631.52 0.00 9,207.47 13,400.00 90.69 324.94 6,929.45 6,879.85 8,078.42 -4,715.79 6,011,976.38 383,575.32 0.00 9,307.45 13,500.00 90.69 324.94 6,928.25 6,878.65 8,160.27 -4,773.23 6,012,059.07 383,519.12 0.00 9,407.43 13,600.00 90.69 324.94 6,927.05 6,877.45 8,242.12 -4,830.67 6,012,141.77 383,462.92 -0.00 9,507.41 13,700.00 90.69 324.94 6,925.85 6,876.25 8,323.97 -4,888.11 6,012,224.46 383,406.72 0.00 9,607.39 13,800.00 90.69 324.94 6,924.65 6,875.05 8,405.82 -4,945.54 6,012,307.16 383,350.52 0.00 9,707.37 13,900.00 90.69 324.94 6,923.45 6,873.85 8,487.67 -5,002.98 6,012,389.85 383,294.32 0.00 9,807.35 14,000.00 90.69 324.94. 6,922.25 6,872.65 8,569.52 -5,060.42 6,012,472.54 383,238.12 0.00 9,907.33 14,100.00 90.69 324.94 6,921.05 6,871.45 8,651.37 -5,117.86 6,012,555.24 383,181.92 0.00 10,007.31 14,200.00 90.69 324.94 6,919.85 6,870.25 8,733.22 -5,175.30 6,012,637.93 383,125.72 0.00 10,107.29 220/2006 10:20:40AM Page 6 of 8 COMPASS 2003.11 Buiid 50 ORIGINAL • • " ' Sperry Drilling Services HtAL~t~~..I~r~TC~ ~C?I 1t)Ct~P~ 1~~35' Planning Report -Geographic ---- ---------~-- Af~slc;~ Sherry DrilliAg Se~rt~es Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-111 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River Unit MD Reference: 'Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-111 Design: CD3-111wp02 Planned Survey CD3-111wp02 Map Map MD Inclinatio n Azimuth TVD SSTVD +NI-S +EI-W' Northing Easting DL5EV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ftl (ftl {,°1100ft) {ft) 14,300.00 90.69 324.94 6,918.65 6,869.05 8,815.07 -5,232.74 6,012,720.63 383,069.52 0.00 10,207.26 14,400.00 90.69 324.94 6,917.45 6,867.85 8,896.92 -5,290.17 6,012,803.32 383,013.32 0.00 10,307.24 14,500.00 90.69 324.94 6,916.25 6,866.65 8,978.77 -5,347.61 6,012,886.01 382,957.12 0.00 10,407.22 14,600.00 90.69 324.94 6,915.05 6,865.45 9,060.62 -5,405.05 6,012,968.71 382,900.91 0.00 10,507.20 14,700.00 90.69 324.94 6,913.85 6,864.25 9,142.47 -5,462.49 6,013,051.40 382,844.71 0.00 10,607.18 14,800.00 90.69 324.94 6,912.65 6,863.05 9,224.32 -5,519.93 6,013,134.10 382,788.51 0.00 10,707.16 14,900.00 90.69 324.94 6,911.45 6,861.85 9,306.17 -5,577.36 6,013,216.79 382,732.31 0.00 10,807.14 15,000.00 90.69 324.94 6,910.25 6,860.65 9,388.02 -5,634.80 6,013,299.49 382,676.11 0.00 10,907.12 15,100.00 90.69 324.94 6,909.05 6,859.45 9,469.87 -5,692.24 6,013,382.18 382,619.91 0.00 11,007.10 15,200.00 90.69 324.94 6,907.85 6,858.25 9,551.72 -5,749.68 6,013,464.87 382,563.71 0.00 11,107.08 15,300.00 90.69 324.94 6,906.65 6,857.05 9,633.57 -5,807.12 6,013,547.57 382,507.51 0.00 11,207.06 15,400.00 90.69 324.94 6,905.45 6,855.85 9,715.42 -5,864.56 6,013,630.26 382,451.31 0.00 11,307.04 15,500.00 90.69 324.94 6,904.25 6,854.65 9,797.27 -5,921.99 6,013,712.96 382,395.11 0.00 11,407.02 15,600.00 90.69 324.94 6,903.05 6,853.45 9,879.12 -5,979.43 6,013,795.65 382,338.91 0.00 11,507.00 15,700.00 90.69 324.94 6,901.85 6,852.25 9,960.97 -6,036.87 6,013,878.34 382,282.71 0.00 11,606.97 15,800.00 90.69 324.94 6,900.65 6,851.05 10,042.82 -6,094.31 6,013,961.04 382,226.51 0.00 11,706.95 15,900.00 90.69 324.94 6,899.45 6,849.85 10,124.67 -6,151.75 6,014,043.73 382,170.30 0.00 11,806.93 16,000.00 90.69 324.94 6,898.25 6,848.65 10,206.52 -6,209.18 6,014,126.43 382,114.10 0.00 11,906.91 16,100.00 90.69 324.94 6,897.05 6,847.45 10,288.37 -6,266.62 6,014,209.12 382,057.90 0.00 12,006.89 16,200.00 90.69 324.94 6,895.86 6,846.26 10,370.22 -6,324.06 6,014,291.82 382,001.70 0.00 12,106.87 16,300.00 90.69 324.94 6,894.66 6,845.06 10,452.07 -6,381.50 6,014,374.51 381,945.50 0.00 12,206.85 16,400.00 90.69 324.94 6,893.46 6,843.86 10,533.92 -6,438.94 6,014,457.20 381,889.30 0.00 12,306.83 16,500.00 90.69 324.94 6,892.26 6,842.66 10,615.77 -6,496.38 6,014,539.90 381,833.10 0.00 12,406.81 16,554.66 90.69 ~ 324.94 6,891.60 6,842.00 10,660.51 -6,527.77 6,014,585.10 381,802.38 0.00 12,461.46 Target (Toe); 16554.66' MD, 6891. 60' TVD, 143 1.91' FSL, 520.65' FWL, Sec30 - T13N - R05E - 6-118" Open Hole -CD3-111wp02 Toe - -._ - >Geologic Targets Plan: CD3-111 ~ TVD (ft) 6,981.60 - Point 6,891.60 - Point Prognosed Casing Points Measured Depth (ft) 2,750.33 9,053.28 16,554.65 Target Name +N/-S +E/-W Northing Easting -Shape ft ft (ft) (ft) CD3-111wp02 Heel 4,520.63 -2,219.12 6,008,381.90 386,018.21 CD3-111wp02 Toe 10,660.51 -6,527.77 6,014,585.10 381,802.38 Vertical Casing Hole Depth Diameter Diameter 2,500.00 9-5/8 12-1 /4 6,981.60 7 8-314 6,891.60 6-1 /8 6-1/8 220/2006 10:20:40AM Page 7 of 8 COMPASS 2003.11 Build 50 ORIGINAL ~ ~r-'' S er Drillin Services P rY 9 - - ~' ~~-~~s~~~ ~ ®t~ ~t)t1QCtJP 1i~1 S Planning Report - Geographic --- --- -----~- Alaska Sperry D€illing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD3-111 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Project: Colville River U nit MD Reference: Planned Doyon 19 @ 49.60ft (Doyon 19 (36.3 + 13.3)) Site: Alpine CD3 North Reference: True Well: Plan: CD3-111 Survey Calculatio n Method: Minimum Curvature Welibore: Plan: CD3-111 Desigr- CD3-111wp02 Prognosed Form ation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +Fr-W ~~) (°S (.,~ (ft1 Ift) (ftl Name 1,270.37 21.76 336.16 1,249.60 149.36 -66.01 Base Permafrost 2,556.23 34.27 336.16 2,339.60 768.43 -339.61 C-40 2,749.84 34.27 336.16 2,499.60 868.15 -383.68 C-30 3,219.34 34.27 336.16 2,887.60 1,109.95 -490.54 C-20 4,443.92 34.27 336.16 3,899.60 1,740.63 -769.27 K-3 4,624.22 34.27 336.16 4,048.60 1,833.49 -810.31 K-3 Basal 4,661.74 34.27 336.16 4,079.60 1,852.81 -818,85 K-2 4,788.79 34.27 336.16 4,184.60 1,918.25 -847.77 K-2 Basal 6,652.28 34.27 336.16 5,724.60 2,877.98 -1,271.93 Aibian 97 6,972.95 34.27 336.16 5,989.60 3,043.13 -1,344.92 Aibian 96 7,713.99 50.92 331.16 6,549.60 3,473.95 -1,556.38 Top HRZ 7,978.04 58.74 329.61 6,701.60 3,661.37 -1,663.07 Base HRZ 8,068.25 61.41 329.14 6,746.60 3,728.64 -1,702.90 K-1 8,160.06 64.14 328.69 6,788.60 3,798.54 -1,745.05 Top Kuparuk D 8,259.36 67.08 328.22 6,829.60 3,875.60 -1,792.37 Top Kuparuk C 8,272.31 67.47 328.16 6,834.60 3,885.74 -1,798.66 LCU 8,272.31 67.47 328.16 6,834.60 3,885.74 -1,798.66 Top Nuiqsut 8,445.17 72.60 327.39 6,893.60 4,023.14 -1,885.29 Base Nuiqsut 8,813.80 83.56 325.88 6,969.60 4,323.86 -2,083.42 Top Nechelik 2/20/2006 10:20:40AM Page 8 of 8 COMPASS 2003.11 Build 50 r • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-111 Plan: CD3-111 CD3-111wp02 Anticollision Report 15 February, 2006 A~~~ Sperry C~r~lin+~ ~erv~ces O~,IGIIVAL ,~,.~ ANTE-COLL(:ipN SETTINGS /~ [ [, AV~Ii~4/f/1~~'~C~ L~ InterpolatlonMeMOd MD I terval:3691atlons CakulatlonMeNod. MlnlmumCUrvature Critical Issues: p 1e~/~ A~./~e.V 1. l +~ bepM Ranpo f-om. 7870? 186fi4.e6 Error Model: ISG WSA rr~a~~,,,,~~~~„,„,,, fi3P+`nKa Maelmum Ranpa: 1861.8 76 3 0 71611 Scan Mathod: Trav. Cytindei Hwth Ertor Suriace: EIIipOCalCOnlc Reference Well: Plm: CD7-171vry02 Warning Methotl: Rubs Based ~~ (-(-,~~(,Ji~'+'~ CI'~RY'FY PR(1C RAhi g~~ ~~'I,A~ ~~~~,~ Date: 3186-02153 W x1.0(1 1'elid [ed: Yes Ycrsi~ n ', Depth From Drprli T.. Su~~e~/Ran FaW o+•=~•'- ~- 36.31) R(111tx) CD3-IIInp02 CH-CYROSS Nn0.fa1 16554.66 CD3-11I~p02 MvYD~IFR-AK-CAZSC a Ah#alnc LbnornPM1ili --- -J~ p FrojxF CoNI~b RHx Unl Sae Npne CD7 L`A& Pen. C03~111 nt aW R. av~roow. ray: CA7an a.µ a raox r aaroaRr a- p m°~ni fmislxr.,oan >w.~~ail4Jrln."n"~ m wm a.~uv~ ii6 o.aoAlooym+sRea.raa8 a e.,.e. »e.m. c ce~e --- - 100 --- -~_.- 1 ~~n= '~ - lox -- _ ~~~n ~~ ~ ~$o _ ~~_~_ ~, j , ~ I j GD3-110 Rig Surveys j 70 / ~~ ~~ ~ ~ , y ~. ~, i60 ~ ~~ \\ ~ Plan: CD3-107 (wp01) 30AF ~ ~ 50 ~ j ~ ~ ~` : cDa-1os (wpol) ~ / 40 ~~ ~' ~ ~t~- a~>~~ ~' Ill n I ~ ~ X30 j~ 1 ~ W ~ ~ y'` ~~ o ~, I ~ ~' y I ~" 270 _j- I j: 6 , ~~ 1 d ~' ~ ~ X, ~~ ~/ ~ ` 90 ."11 , .~ t ,•, ~vk ~y ~ j ~~1,~ ~ 1 ~ I - ~~ ~~ ~ 1y~ t~ ~~ n '~- ~ ~ ~ ~; _ ~ °; t~ ` 0-~ ,' -`~- = D3-109wp08 /{~~ j ~~v ~ ~/ i j 1 j ~~ ti ~ .~y ~ '`, /~r ~ Cp3-109 Rig Surveys j t ~_ ~ ~ ~ ; ~'A ~ j ll ~ /]~ ~~rt 4 "+,~ ~ ~ 24 ~,~ /;;~~ ~~~~~` ~~ ~~~ ~~~ ~ ;' X120 ~^ ` < Plan: CD3-115 (wp01) ~ t ~ ~ _ °I '~j k~ i ~~ 1f I1 // j YY ~ \ y ~ ly 1 k f t ` ~~~Q ~ A ~ • ~ ~ / \ 21~ 1>, _ y ~ / ~ . ` F j ~~ ~ ~~9 j~ ~ I ~, ,.~ 'C50 ~, ~~ ,; r ... Plan: CD3-114 (wp01) ~ ~ - ~- ' ~~ ~ " ~ ~~-°` ~_~_ =rso 1, Plan: CD3-112 Plan : CD3-113 (wp01) Travelling Cylind er Pr~imutL ('CFS)~riZl) (°J r8 Centre fa CeM1~0 5epxr8ti0n (10 Win] 27 90 0 s ravenn>; s;ylm0er arlmum 1 snmaau 1-1 vs crn rce m s:enrc e aepnranml p maul SECTION DETAILS Sec MD Inc AzI TVD +N/S +&-W DLeg TFace VSec Tergef 1 36.30 0.00 0.00 76 30 0.00 0.00 000 0011 0.00 2 4aa.oo o.oa o.ao 4an.ao a.lro o.oo o.oo o.oo a.ao 3 1770.75 34.27 336.16 1690.47 363.90 -160.83 2..50 0.00 788.91 4 7148.11 34.27 736.16 6134.36 3ll3.J5 -1384.78 000 O.OD 3348.89 5 9057.28 90.69 724.94 6981.60 4520.67 -2219.12 3.00 -13.39 4961.63 CD3-111wp02 Heel 6 165W.66 90.69 324.94 6891.60 10660.51 fi527.77 0.00 0.00 12461.46 CD3-111wp02Tce CD3-111wp02 36.30 To 16554.66 Q CD3-110 Rig Surveys • 2/15/2006 10:37 AM 180 Plan: CD3-112 - Cc~r~eo~'hilips Alaska Company: ConocoPhillips Alaska Inc. .Project: Colville River Unit Reference Site: Alpine CD3 Site Error: O.OOft Reference Well: Plan: CD3-111 Well Error: O.OOft Reference Wellbore Plan: CD3-111 Reference Design: ' CD3-111wp02 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: P>s Offset TYD Reference: • ~>~~.I~BI~~r~~~N ~..,._ Sperry Drilling ServiC6S Well Plan: 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 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference CD3-111wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,851.84ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 211 512 0 0 6 From To (ft) (ft) Survoy (Wellbore) 36.30 800.00 CD3-111wp02 (Plan: CD3-111) 800.00 16,554.66 CD3-111wp02 (Plan: CD3-111) Summary Site Name Offset Well -Wellbore -Design Alpine CD3 CD3-108 -Rig: CD3-108 -CD3-108 Rig Surveys CD3-109 -Plan: CD3-109 -CD3-109wp08 CD3-109 -Rig: CD3-109 -CD3-109 Rig Surveys CD3-110 -Rig 2: CD3-110 -CD3-110 Rig Survey: CD3-110 -Rig: CD3-110 -CD3-110 Rig Surveys CD3-302 -CD3-302PB1 -CD3-302P61 Rig Surve CD3-302 -Plan: CD3-302 -CD3-302 Rig Surveys CD3-302 -Plan: CD3-302 -CD3-302wp06 Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (~ Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 (~ Plan: CD3-112 -Plan: CD3-112 -Plan: CD3-112 Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 (~ Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 (~ Plan: CD3-115 -Plan: CD3-115 -Plan: CD3-115 (~ Plan: CD3-116 -Plan: CD3-116 -Plan: CD3-116 (~ Plan: CD3-117 -Plan: CD3-117 -Plan: CD3-117 (~ Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp01) Plan: CD3-303 -Plan: CD3-303 -CD3-303wp04 Plan: CD3-303 -Plan: CD3-303P61 -CD3-303P6 Plan: CD3-304 -Plan: CD3-304 -CD3-304wp06 Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 (~ Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 275.98 275.00 61.40 5.10 56.30 Pass -Major Risk 424.79 425.00 41.47 9.13 32.34 Pass -Major Risk 424.79 425.00 41.47 9.13 32.34 Pass -Major Risk 323.70 325.00 21.35 6.74 14.61 Pass -Major Risk 323.70 325.00 21.35 6.74 14.61 Pass -Major Risk 248.80 250.00 180.39 5.22 175.17 Pass -Major Risk 248.80 250.00 180.39 5.22 175.17 Pass -Major Risk 248.80 250.00 180.39 5.22 175.17 Pass -Major Risk 250.99 250.00 100.40 5.19 95.21 Pass -Major Risk 250.99 250.00 80.37 4.66 75.71 Pass -Major Risk 600.82 600.00 20.46 11.23 9.24 Pass -Major Risk 650.80 650.00 40.08 12.17 27.91 Pass -Major Risk 626.34 625.00 59.43 11.70 47.73 Pass -Major Risk 451.31 450.00 80.80 8.40 72.39 Pass -Major Risk 226.00 225.00 100.41 4.18 96.23 Pass -Major Risk 226.00 225.00 120.39 4.18 116.20 Pass -Major Risk 400.94 400.00 200.59 7.47 193.13 Pass -Major Risk 373.79 375.00 160.80 7.87 152.94 Pass -Major Risk 374.89 375.00 160.83 7.89 152.94 Pass -Major Risk 374.99 375.00 140.57 7.89 132.68 Pass -Major Risk 250.99 250.00 120.26 4.65 115.61 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/152006 10:32:55AM Page 2 of 2 COMPASS 2003.11 Build 50 ^'?!61NAL • • ~y~~ ~W~g 0 ° m ~a~a ~ zsm$ rm~ 0 orb nx ~ ~_.,., ~ av ~~ xo '~, ~ N rn O . .. ! - -~ I ~ ~ m N ~ ~U~D 3 7 , ~ ~ N UU ~ N m 16 R • Q.. lh .~ _~.~ } oaa ~ ~ '9 , R U ~ 0 Q, ?f ~ 0 J .., W i~in~n __ m 0 `~ c o ?~ ~ a` a ~ O _ c _....._ m _..... ~ _..... _ ....... _ _ ' _....... _ .... o O o w J a - ~ 'O i ' - / ~ 0 0 `py ,' ~ ~ p r ~ / ti 2 ~ ~ ~ ~ =E z'° i o0 E °° °_ ~ ~ , ~o -:ate C G ~~s~"_~, ~ O _U oCp4G ~ ~H W ~ ~ZG sgeg~ ~ p , a ~ c^ O m o ..~ 'sW;°t3°~ c ~ ~ °n ......... ...... i 00 s' m m ~a~~, i U B C ~Y~i< ~a¢. ~ ~~ o t .,_ `~ `a u%5 z ~. ~ ~ ..._... ......... ___.- -- --..... .... - ... .. -__-... ....... ----............ .._._ -- _-- ......._. •-__. __.... O In ,je ~~ ~ ~ ..... ... .... _ ._ wru ~ ~ ~ i gQ~ L ' 1M ~ . O O O O O O ~. ~ ~ O ~ O ~ y~~j ~ ~ O I~ ~ N l~!M OOSZ)1+)43~ON/1-)43~OS ORIGINAL ~"' ~' ConaccPhillips Alaska Biperry ©1^flltng S~rvicell Project: Colville River Unit Site: Alpine CD3 ' Well: Plan: CD3-111 Wellbore: Plan: CD3-111 Plan: CD3-111wp02 Ground level; 13.70 RftB: Planned DOyon 19 QR49.SOft {DO}ron 19 (35.3+13,J1f NorihinglASP Y; $OO7$2a.92 . EastinglASP K; 38$189.17 F ~~ - s. ~~, ,~,£ ^ ,... CD3-110, Rig 2: CD3-110, CD3-110wp06 VO CD3-110, Rig 2: CD3-110, CD3-110 Rig Surveys VO CD3-111wp02 \F • • Closest in POOL °~~ .~ +.J ~-+~ i Closest A roach: Reference Well : CD3-1 11w 02 Plan offset Well: GD3-110 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Distance Difference De ih Incl. An le TRUE Azi. TVD E + /W _ 351.36° Comments De th Incl. An le TRUE Azi. TVD E + /W - 351.36° Comments POOL Min Distance POOL Min Distance (2067.24 ft) in POOL (2067.24 ft) in POOL (6822 - 6952 Subsea (6822 - 6952 Subsea TVD) to CD3-110 Rig TVD) to CD3-110 Rig 2067.24 2067.22 8.6374851 10400 90.69 324.94 6915.746 6009496 385261.4 6308.111 Surveys 8460 75.47 327.63 6882.397 6007975 388894.9 2973.138 Surveys The following well is a Well Plan that wil l land in Pool Closest A roach: Reference Well : CD3-1 11w 02 Plan Offset WeIL• CD3-1.12 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Distance Difference De th Incl. An le TRUE Azi. TVD E + /W - (351.36° Comments De th Incl. Angle TRUE Azi. TVD E(+)!W(-) 351.36° Comments in is ante in is once (2102.34 ft) in POOL (2102.34 ft) in POOL (6822 - 6952 Subsea (6822 - 6952 Subsea TVD) to CD3- TVD) to CD3- 2102.34 2102.34 3.8731727 9053.28 90.69 324.94 6931.963 6008382 386018.3 4961.67 112wp02 9230 90.78 324.94 6935.837 6007203 384278 4998.788 112wp02 POOL Summaryl.xis 2!17/2006 6:00 PM • • • SHARON K. ALLSUP-DRAKE 1135 CONOCOPHILLIPS ATO 1530 ~ ( ~,~~ J~~~ . ~ 700 G ST. DATE 551/441 ANCHORAGE AK 99501 ~/~ / ~s'//L ~ p~-7/~ PAY 70 THE SlI~~~U~ /7(~~~i-/'7. ~ 1~-L~-t__ ~ ~(/~-`. G`C..~ - ORDER OF /1~ r ., .---" ~~. U/Jr7.tc.- v~G~ ~ ~-~-,~ ~ ~~.G~~---_._..•RS LJ o~3a~•~ ~~ J P M organ Ch ase ~:~ Valid Up To 5000. Dollars JPMorgan Chase Bank, N.A. /~ Columbus, OH F ~j / ~ MEMO ----`~------------- - ~:~44 L L551 L~:S 28747 19079 2711' L L35 a • ~ TRANSMITTAL LETTER CHECKLIST WELL NAME C..~~~ ~-~ -~ - ~~~ PTD# ~= ~ '- ~~ ` 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 wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - 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 well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Com any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl i st • • ^^ ~ y ~ , , m o , d D ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t 3 ~ ~ a ~ , N.. , , m~ N ~ N. 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O U ~ a `n w a ~ h a~ i S Q s • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Welf Permitting Process but is part of the history file. To improve the readability of the Well History fife and to simplify finding information, information of this nature is accumulated ai the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 01 19:06:40 2006 Reel Header Service name .............LISTPE Date .....................06/06/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/06/01 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004254172 R. KRELL D. BURLEY a o6'~- 030 ~ t3~3~ Scientific Technical Services Scientific Technical Services CD3-111 501032052600 ConocoPhillips Alaska, Inc. Sperry Drilling Services O1-JUN-06 MWD RUN 3 MWD RUN 4 MW0004254172 MW0004254172 R. KRELL R. KRELL D. BURLEY 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 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 5 12N 5E 1334 874 49.40 13.30 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 8.750 9.625 6.125 7.000 DRILLERS DEPTH (FT) 2721.0 8660.0 REMARKS: 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. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. 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). 5. 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. 6. MWD RUNS 1-4 REPRESENT WELL CD3-111 WITH API#: 50-103-20526-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15073'MD/6908'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). SCO2 = 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.... ...06/06/01 Maximum Physical Recor d..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 15016.0 NCNT 2700.0 8582.0 NPHI 2700.0 8582.0 FONT 2700.0 8582.0 FET 2710.0 15023.0 RPD 2710.0 15023.0 RPX 2710.0 15023.0 RPS 2710,0 15023.0 RPM 2710.0 15023.0 RHOB 2715.0 15004.5 PEF 2715.0 15004.5 DRHO 2715,0 15004.5 ROP 2731.5 15073.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2697.5 8670.0 MWD 3 8670.0 10657.0 MWD 4 10657.0 15073.0 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 Data Reference Point ..............Undefined Frame Spacing .....................60 .12N 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 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2697.5 15073 8885.25 24752 2697.5 15073 FONT 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 2.4077 24580 2715 15004.5 DRHO MWD G/CM -3.692 0.331 0.0285615 24580 2715 15004.5 RPD MWD OHMM 0.2 2000 16.5881 24627 2710 15023 RPM MWD OHMM 0.15 2000 13.9366 24627 2710 15023 RPS MWD OHMM 0.18 1653.5 10.8752 24627 2710 15023 RPX MWD OHMM 0.16 1654.73 9.48239 24627 2710 15023 FET MWD HOUR 0.15 70.04 0.967471 24627 2710 15023 GR MWD API 25.9 416.6 79.8535 24638 2697.5 15016 PEF MWD BARN 0.89 13.4 2.37571 24580 2715 15004.5 ROP MWD FT/H 1.11 332.52 152.189 24684 2731.5 15073 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...........15073 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/01 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.......06/06/01 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 BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 2697.5 NCNT 2700.0 NPHI 2700.0 STOP DEPTH 8635.5 8582.0 8582.0 • FCNT 2700.0 8582.0 RPS 2710.0 8627.5 RPM 2710.0 8627.5 FET 2710.0 8627.5 RPX 2710.0 8627.5 RPD 2710.0 8627.5 RHOB 2715.0 8595.0 PEF 2715.0 8595.0 DRHO 2715.0 8595.0 ROP 2731.5 8670.0 LOG HEADER DATA DATE LOGGED: 11-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8670.0 TOP LOG INTERVAL (FT) 2731.0 BOTTOM LOG INTERVAL (FT) 8670.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 32.4 MAXIMUM ANGLE: 84.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 96540 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 10507541 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2721.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S): 42.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.650 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.390 143.6 MUD FILTRATE AT MT: 2.350 72.0 MUD CAKE AT MT: 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 FONT 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.......06/06/01 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.......06/06/01 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 PEF 8595.5 10588.5 DRHO 8595.5 10588.5 RHOB 8595.5 10588.5 RPM 8628.0 10607.0 RPX 8628.0 10607.0 RPS 8628.0 10607.0 FET 8628.0 10607.0 RPD 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): DRILLER'S CASING DEPTH (FT): 6.125 8660.0 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Polymer 9.20 48.0 9.9 31000 3.2 .300 72.0 .150 155.5 .180 72.0 .140 72.0 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 r~ L 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 1 653.5 14.7822 3959 8628 10607 RPX MWD030 OHMM 0.16 16 54.73 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 2 04.12 114.453 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.......06/06/01 Maximum Physical Record..65535 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.......06/06/01 Maximum Physical Record..65535 File Type .............. 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 RHOB 10589.0 15004.5 DRHO 10589.0 15004.5 PEF 10589.0 15004.5 GR 10600.5 15016.0 RPD 10607.5 15023.0 RPM 10607.5 15023.0 RPX 10607.5 15023.0 FET 10607.5 15023.0 RPS 10607.5 15023.0 ROP 10657.5 15073.0 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) 15073.0 TOP LOG INTERVAL (FT) 10657.0 BOTTOM LOG INTERVAL (FT) 15073.0 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): 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 6.125 8660.0 Polymer 9.25 42.0 9.3 29000 3.2 160 68.0 070 162.0 140 68.0 230 68.0 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 I1 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10589 15073 12831 8969 10589 15073 RHOB MWD040 G/CM 2.217 3.01 2.41613 8832 10589 15004.5 DRHO MWD040 G/CM -0.127 0.253 0.0652084 8832 10589 15004.5 RPD MWD040 OHMM 9.72 50.35 17.8305 8832 10607.5 15023 RPM MWD040 OHMM 8.9 56.24 17.1928 8832 10607.5 15023 RPS MWD040 OHMM 8.59 62.64 17.1942 8832 10607.5 15023 RPX MWD040 OHMM 6.92 41.29 14.564 8832 10607.5 15023 FET MWD040 HOUR 0.26 28.58 0.937811 8832 10607.5 15023 GR MWD040 API 26.59 65.47 46.3096 8832 10600.5 15016 PEF MWD040 BARN 0.89 6.38 1.74668 8832 10589 15004.5 ROP MWD040 FT/H 1.11 319.15 132.8 8832 10657.5 15073 First Reading For Entire File..........10589 Last Reading For Entire File...........15073 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/01 Origin ..................~S Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/06/01 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
